US9847639B2 - Electric power system control with measurement of energy demand and energy efficiency - Google Patents

Electric power system control with measurement of energy demand and energy efficiency Download PDF

Info

Publication number
US9847639B2
US9847639B2 US15/009,016 US201615009016A US9847639B2 US 9847639 B2 US9847639 B2 US 9847639B2 US 201615009016 A US201615009016 A US 201615009016A US 9847639 B2 US9847639 B2 US 9847639B2
Authority
US
United States
Prior art keywords
voltage
energy
filter
data
predetermined
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
US15/009,016
Other versions
US20160164290A1 (en
Inventor
Edmund J. Hall
Stephen J. Tyler
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Dominion Energy Inc
Original Assignee
Dominion Energy Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority to US201361789085P priority Critical
Priority to US14/193,980 priority patent/US9563218B2/en
Priority to US201562109322P priority
Application filed by Dominion Energy Inc filed Critical Dominion Energy Inc
Priority to US15/009,016 priority patent/US9847639B2/en
Publication of US20160164290A1 publication Critical patent/US20160164290A1/en
Assigned to DOMINION RESOURCES, INC. reassignment DOMINION RESOURCES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: HALL, EDMUND J., TYLER, STEPHEN J.
Assigned to DOMINION ENERGY, INC. reassignment DOMINION ENERGY, INC. CHANGE OF NAME (SEE DOCUMENT FOR DETAILS). Assignors: DOMINION RESOURCES, INC.
Application granted granted Critical
Publication of US9847639B2 publication Critical patent/US9847639B2/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/12—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load
    • G—PHYSICS
    • G05—CONTROLLING; REGULATING
    • G05B—CONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
    • G05B15/00—Systems controlled by a computer
    • G05B15/02—Systems controlled by a computer electric
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING; COUNTING
    • G06Q—DATA PROCESSING SYSTEMS OR METHODS, SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL, SUPERVISORY OR FORECASTING PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL, SUPERVISORY OR FORECASTING PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q10/00—Administration; Management
    • G06Q10/04—Forecasting or optimisation, e.g. linear programming, "travelling salesman problem" or "cutting stock problem"
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/003—Load forecast, e.g. methods or systems for forecasting future load demand
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/12—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load
    • H02J3/14—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load by switching loads on to, or off from, network, e.g. progressively balanced loading
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/24—Arrangements for preventing or reducing oscillations of power in networks
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R19/00—Arrangements for measuring currents or voltages or for indicating presence or sign thereof
    • G01R19/25—Arrangements for measuring currents or voltages or for indicating presence or sign thereof using digital measurement techniques
    • G01R19/2513—Arrangements for monitoring electric power systems, e.g. power lines or loads; Logging
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING; COUNTING
    • G06Q—DATA PROCESSING SYSTEMS OR METHODS, SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL, SUPERVISORY OR FORECASTING PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL, SUPERVISORY OR FORECASTING PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
    • G06Q50/06—Electricity, gas or water supply
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00004—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by the power network being locally controlled
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00016—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using a wired telecommunication network or a data transmission bus
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00016—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using a wired telecommunication network or a data transmission bus
    • H02J13/00017—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using a wired telecommunication network or a data transmission bus using optical fiber
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00022—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using wireless data transmission
    • H02J13/00024—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using wireless data transmission by means of mobile telephony
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00022—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using wireless data transmission
    • H02J13/00026—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using wireless data transmission involving a local wireless network, e.g. Wi-Fi, ZigBee or Bluetooth
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00034—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving an electric power substation
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/0006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks
    • H02J13/0013—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit
    • H02J13/0017—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit with direct transmission between the control or monitoring unit and the controlled or monitored unit
    • H02J13/0062—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit with direct transmission between the control or monitoring unit and the controlled or monitored unit using a data transmission bus
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/0006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks
    • H02J13/0013—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit
    • H02J13/0017—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit with direct transmission between the control or monitoring unit and the controlled or monitored unit
    • H02J13/0075—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network for single frequency AC networks characterised by transmission structure between the control or monitoring unit and the controlled or monitored unit with direct transmission between the control or monitoring unit and the controlled or monitored unit using radio means
    • H02J2003/003—
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
    • H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2310/00—The network for supplying or distributing electric power characterised by its spatial reach or by the load
    • H02J2310/10—The network having a local or delimited stationary reach
    • H02J2310/12—The local stationary network supplying a household or a building
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B70/00—Technologies for an efficient end-user side electric power management and consumption
    • Y02B70/30—Systems integrating technologies related to power network operation and communication or information technologies for improving the carbon footprint of the management of residential or tertiary loads, i.e. smart grids as climate change mitigation technology in the buildings sector, including also the last stages of power distribution and the control, monitoring or operating management systems at local level
    • Y02B70/3225—Demand response systems, e.g. load shedding, peak shaving
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B90/00—Enabling technologies or technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02B90/20—Smart grids as enabling technology in buildings sector
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E40/00—Technologies for an efficient electrical power generation, transmission or distribution
    • Y02E40/70—Smart grids as climate change mitigation technology in the energy generation sector
    • Y02E40/76—
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S10/00—Systems supporting electrical power generation, transmission or distribution
    • Y04S10/50—Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications
    • Y04S10/54—
    • Y04S10/545—
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/20—End-user application control systems
    • Y04S20/222—Demand response systems, e.g. load shedding, peak shaving
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S40/00—Systems for electrical power generation, transmission, distribution or end-user application management characterised by the use of communication or information technologies, or communication or information technology specific aspects supporting them
    • Y04S40/20—Information technology specific aspects, e.g. CAD, simulation, modelling, system security

Abstract

A method, apparatus, system and computer program is provided for controlling an electric power system, including implementation of voltage measurement using paired comparison analysis applied to calculating a shift in average usage per customer from one time period to another time period for a given electrical use population where the pairing process is optimized using a novel technique to improve the accuracy of the measurement.

Description

This application claims priority under 35 U.S.C. §119(e) to U.S. Provisional Patent Application Ser. No. 62/109,322 filed on Jan. 29, 2015, which is hereby incorporated by reference in its entirety. This application is also a continuation-in-part to U.S. patent application Ser. No. 14/193,980, filed Feb. 28, 2014, which claims priority under 35 U.S.C. §119(e) to U.S. Provisional Patent Application Ser. No. 61/789,085, filed Mar. 15, 2013, which are each hereby incorporated by reference in their entirety.
BACKGROUND
The present disclosure relates to a method, an apparatus, a system and a computer program for controlling an electric power system, including measuring the effects of optimizing voltage, conserving energy, and reducing demand using t distributions. More particularly, the disclosure relates to a novel implementation of electrical demand and energy efficiency improvement measurement using a paired samples t-test to compare the population demand and energy usage over a specific time period. This method enables the direct statistical measurement of energy and demand changes between two time periods for an energy use population. This comparison can be used as a basis to accurately quantify energy efficiency and demand reduction values for savings resulting from implementation of a modification to the electric power system.
Electricity is commonly generated at a power station by electromechanical generators, which are typically driven by heat engines fueled by chemical combustion or nuclear fission, or driven by kinetic energy flowing from water or wind. The electricity is generally supplied to end users through transmission grids as an alternating current signal. The transmission grids may include a network of power stations, transmission circuits, substations, and the like.
The generated electricity is typically stepped-up in voltage using, for example, generating step-up transformers, before supplying the electricity to a transmission system. Stepping up the voltage improves transmission efficiency by reducing the electrical current flowing in the transmission system conductors, while keeping the power transmitted nearly equal to the power input. The stepped-up voltage electricity is then transmitted through the transmission system to a distribution system, which distributes the electricity to end users. The distribution system may include a network that carries electricity from the transmission system and delivering it to end users. Typically, the network may include medium-voltage (for example, less than 69 kV) power lines, electrical substations, transformers, low-voltage (for example, less than 1 kV) distribution wiring, electric meters, and the like.
The following, the entirety of which is herein incorporated by reference, describe subject matter related to power generation or distribution: Power Distribution Planning Reference Book, Second Edition, H. Lee Willis, 2004; Estimating Methodology for a Large Regional Application of Conservation Voltage Reduction, J. G. De Steese, S. B. Merrick, B. W. Kennedy, IEEE Transactions on Power Systems, 1990; Implementation of Conservation Voltage Reduction at Commonwealth Edison, IEEE Transactions on Power Systems, D. Kirshner, 1990; Conservation Voltage Reduction at Northeast Utilities, D. M. Lauria, IEEE, 1987; Green Circuit Field Demonstrations, EPRI, Palo Alto, Calif., 2009, Report 1016520; Evaluation of Conservation Voltage Reduction (CVR) on a National Level, PNNL-19596, Prepared for the U.S. Department of Energy under Contract DE-ACO5-76RL01830, Pacific Northwest National Lab, July 2010; Utility Distribution System Efficiency Initiative (DEI) Phase 1, Final Market Progress Evaluation Report, No 3, E08-192 (July 2008) E08-192; Simplified Voltage Optimization (VO) Measurement and Verification Protocol, Simplified VO M&V Protocol Version 1.0, May 4, 2010; MINITAB Handbook, Updated for Release 14, fifth edition, Barbara Ryan, Brian Joiner, Jonathan Cryer, Brooks/Cole-Thomson, 2005; Minitab Software, http://www.minitab.com/en-US/products/minitab/; Statistical Software provided by Minitab Corporation.
Further, U.S. patent application Ser. No. 61/176,398, filed on May 7, 2009 and US publication 2013/0030591 entitled VOLTAGE CONSERVATION USING ADVANCED METERING INFRASTRUCTURE AND SUBSTATION CENTRALIZED VOLTAGE CONTROL, the entirety of which is herein incorporated by reference, describe a voltage control and energy conservation system for an electric power transmission and distribution grid configured to supply electric power to a plurality of user locations.
SUMMARY
Various embodiments described herein provide a novel method, apparatus, system and computer program for controlling an electric power system, including implementation of voltage measurement using paired t statistical analysis applied to calculating a shift in average usage per customer from one time period to another time period for a given electrical use population where the pairing process is optimized using a novel technique to improve the accuracy of the statistical measurement.
According to an aspect of the disclosure, the energy validation process (EVP) measures the level of change in energy usage for the electrical energy delivery system (EEDS) that is made up of an energy supply system (ESS) that connects electrically to one or more energy usage systems (EUS). A modification is made to the operation of the EEDS or to an energy usage device (EUD) at some electrical point on an electrical energy delivery system (EEDS) made up of many energy usage devices randomly using energy at any given time during the measurement. The purpose of the energy validation process (EVP) is to measure the level of change in energy usage for the EEDS. The electrical energy supply to the electrical energy delivery system (EEDS) is measured in watts, kilowatts (kw), or Megawatts (MW) (a) at the supply point of the ESS and (b) at the energy user system (EUS) or meter point. This measurement records the average usage of energy (AUE) at each of the supply and meter points over set time periods such as one hour.
The test for the level of change in energy use is divided into two basic time periods: The first is the time period when the modification is not operating, i.e., in the “OFF” state. The second time period is when the modification is operating, i.e., in the “ON” state. Because electrical energy usage is not constant but varies with other independent variables such as weather and ambient conditions, weather and ambient variation as well as other independent variables must be eliminated from the comparison of the “OFF” state to the “ON” state. The intent is to leave only the one independent variable being measured in the comparison of average energy usage from the “OFF” to the “ON” condition.
To eliminate the effect of the ambient and/or weather conditions a pairing process is used to match energy periods with common ambient and/or weather conditions using a pairing process. As an example, temperature, heating degree, cooling degree and other weather conditions are recorded for each energy measurement over the set time periods. These periods are paired if the temperature, heating degree, cooling degree and other weather conditions match according to an optimization process for selecting the most accurate pairs.
To eliminate other independent variables not being measured that will cause variation in the measurement, an EEDS of a near identical energy supply system and near identical energy usage system that is located in the same ambient and/or weather system is used. To eliminate the other independent variables, the changes in energy in the EEDS of a near identical energy supply system are subtracted from the changes measured by the EEDS under test. This method corrects the test circuit for the effects of the other remaining independent variables.
The measurement process consists of first pairing intervals of average energy usage data from the “OFF” state to the “ON” state. The first step is to eliminate significant outliers that are easily identified as not being associated with the independent variable. As an example, if the expected (based on experience or otherwise) load shift resulting from a modification is a maximum of 2 kw and the data shows a population member with an load shift of 10 MW, this element can be excluded. Exclusion has to be done consistently across the population not to destroy the population normality.
The second step is to set the limits of the pairing process. The limits may be set based, at least in part, on the accuracy desired. The accuracy also depends on the number of data points used. As an example, for temperature difference, a limit might be chosen to be one degree Fahrenheit (F). With this choice of limits, a time period type is chosen over which data measurements are examined. Choice of the time period may depend on what EEDS operating environment conditions are relevant for a chosen analysis. For example, a 24-hour time period may be chosen to include the variation of the measured data over a full day. As another example, a four-hour time period in the evening may be chosen to include the variation of measured data over a peak evening electricity usage period.
During the time period, data is collected from a set of sensors in a portion of the EEDS with the modification in the “ON” state. During the same type time period (which may or may not run concurrently with time period for collection in the “ON” state), data is collected from a group of sensors that are potential pairs to the set from a portion of the EEDS with the modification in the “OFF” state. The pairs are reviewed to assure that the best match of temperature levels between the match is chosen. This process may be repeated for other variables. Once the best group of pairs is identified, a standard process of paired t is applied to determine the average change in energy usage from the “OFF” state to the “ON” state using a t distribution for the group of pairs identified. This process can determine, within a confidence level, the actual range of change in energy use from the “OFF” state to the “ON” state for this population. For this process, measurements can be made at the electrical energy delivery system (EEDS) meter point(s) or at the energy usage systems (EUS) meter point(s) or with the energy usage device (EUD) meter points or any combination of EEDS, EUS and EUD meter points.
The resulting change in energy usage may then be used to control the electric energy delivery system. For example, components of the EEDS may be modified, adjusted, added or deleted, including the addition of capacitor banks, modification of voltage regulators, changes to end-user equipment to modify customer efficiency, and other control actions.
According to a further aspect of the disclosure, the energy validation process (EVP) measures the level of change in energy usage for the electrical energy delivery system (EEDS) that is made up of an energy supply system (ESS) that connects electrically to one or more energy usage systems (EUS). This is similar to the aspect described above, however multiple modifications are made to EEDS operation or to energy usage devices (EUD) at electrical point(s) on an electrical energy delivery system (EEDS) made up of many energy usage devices randomly using energy at any given time during the measurement. The purpose of the energy validation process (EVP) is to measure the level of change in energy usage for the EEDS with combined modifications and with each of the individual modifications. The electrical energy supply to the electrical energy delivery system (EEDS) is measured in watts, kw, or MW (a) at the supply point of the ESS and (b) at the energy user system (EUS) or meter point. This measurement records the average usage of energy (AUE) at each of the supply and meter points over set time periods such as one hour.
The test for the level of change in energy use improvement is divided into two basic time periods: The first is the time period when the modification is not operating, i.e., in the “OFF” state. The second time period is when the modification is operating, i.e., in the “ON” state. Because electrical energy usage is not constant but varies with other independent variable such as weather and ambient conditions, weather and ambient variation as well as other independent variables must be eliminated from the comparison of the “OFF” state to the “ON” state. The intent is to leave only the independent variables being measured in the comparison of average energy usage from the “OFF” to the “ON” condition.
To eliminate the effect of the ambient and/or weather conditions a pairing process is used to match energy periods with common ambient and/or weather conditions using a pairing process. As an example temperature, heating degree, cooling degree and other weather conditions are recorded for each energy measurement over the set time periods. These periods are paired if the temperature, heating degree, cooling degree and other weather conditions match according to an optimization process for selecting the most accurate pairs.
To eliminate other independent variables not being measured that will cause variation in the measurement, an EEDS of a near identical energy supply system and near identical energy usage system that is located in the same ambient and/or weather system is used. To eliminate the other independent variables, the changes in energy in an EEDS of a near identical energy supply system are subtracted from the changes measured by the EEDS under test. This method corrects the test EEDS for the effects of the other remaining independent variables.
The measurement process consists of first pairing intervals of average energy usage data from the “OFF” state to the “ON” state. The first step is to eliminate significant outliers that are easily identified as not being associated with the independent variable. As an example, if the expected load shift for a modification is a maximum of 2 kw and the data shows a population member with a load shift of 10 MW, this element can be excluded. Exclusion has to be done consistently across the population not to destroy the population normality.
The second step is to set the limits of the pairing process. As an example for temperature difference a limit might be chosen to be one degree F. With this choice of limits, similar to the preceding described aspect, a time period is chosen over which data measurements shall be or have been taken from a set of sensors with the modification in the “ON” state, and from a group of sensors that are potential pairs to the set, with the modification in the “OFF” state. The pairs are reviewed to assure that the best match of temperature levels between the match is chosen. This is repeated for other variables and once the best group of pairs is identified, a standard process of paired t is applied to determine the average change in energy usage from the “OFF” state to the “ON” state using a t distribution for the group of pairs identified. This process can determine within a confidence interval the actual range of change in energy use from the “OFF” state to the “ON” state for this population. For this process, measurements can be made at the electrical energy delivery system (EEDS) meter point(s) or at the energy usage systems (EUS) meter point(s) or with the energy usage device (EUD) meter points or any combination of EEDS, EUS and EUD meter points.
The resulting change in energy usage may then be used to control the electric energy delivery system. For example, components of the EEDS may be modified, adjusted, added or deleted, including the addition of capacitor banks, modification of voltage regulators, changes to end-user equipment to modify customer efficiency, and other control actions.
The energy validation process (EVP) may further contain a second independent variable such as humidity that affects the energy usage. The EVP is then used to provide a second pairing variable that is secondary to the first pairing variable. The process pairs the first variable as close as possible with the population “OFF” to “ON” values for the chosen energy intervals. The matching second variable is already matched to the first variable for the interval. A weighed scoring of the pairs is implemented based on the relative slopes of the linear relationship between the energy and the respective independent variable. This produces an optimized selection of pairs to most closely match the two population points. This linear optimal matching provides the best pairing of the data for t-distribution evaluation. This method allows multiple values to be optimally paired for calculating average energy changes using the t-distribution.
The energy validation process (EVP) may further contain an electrical energy delivery system (EEDS) that is made up of an energy supply system (ESS) that connects electrically to one or more energy usage systems (EUS) that has three phases of power. The EVP will then perform all power and independent variable calculations by phase values in all combinations of EEDS, ESS, EUS, and EUDs to calculate the energy changes due to modifications in the energy systems. Thus calculations may be performed separately using data for sensed properties specific to each of one of the three phases. In this way, the effects of the modifications to the EEDS for one or more phases may be compared to its effects for the other phase(s).
The energy validation process (EVP) may further contain a second independent variable such as voltage where the ratio of the average change in voltage to average change in energy is being calculated or the conservation voltage reduction factor (CVRF). This factor measures the capacity of the EEDS, EUS and EUD's to change energy usage in response to the independent variable of voltage. The EVP calculates the CVRF first by pairing two energy states from the “OFF” state to the “ON” state as already described. Second the ratio of the percent change in energy divided by the percent change in voltage for the sample is calculated between the two states for each sample in the population. Optimal pairing matches the closest samples for evaluation using a t-distribution to determine the confidence interval for the average value of the CVRF.
The energy validation process (EVP) may further contain multiple independent variables such as voltage and circuit unbalance where the ratio of the average change in voltage and circuit unbalance to average change in energy is being calculated or the energy reduction factor (ERF). This factor measures the capacity of the EEDS, EUS and EUD's to change energy usage in response to multiple independent variables. The EVP calculates the ERF first by pairing two energy states from the “OFF” state to the “ON” state as already described. Second the ratio of the change in energy divided by the change in combined % change of the multiple variables for the sample is calculated between the two states for each sample in the population. Optimal pairing matches the closest samples for evaluation using a t-distribution to determine the confidence interval for the average value of the ERF.
The energy validation process (EVP) may further contain an electrical energy delivery system (EEDS) that is made up of an energy supply system (ESS) that connects electrically to one or more energy usage systems (EUS). The EVP evaluation time period (or interval) can be developed in multiple levels. This is useful to categorize the connected EUD's using a linear regression technique. As a starting point the interval could use the standard interval of 24 hours to capture the effects of load cycling over multiple hours. But in some cases not all loads will be connected during the full 24 hours and the energy measurements may not be consistent over the total period. To address this, for example, evaluations are separated into seasons to represent the different loads, such as air conditioning and heating between the summer and winter seasons respectively. In the fall and spring these loads may not exist under mild weather conditions, so they are evaluated separately as well. In addition each season is evaluated by using linear regression to represent the multiple variables that affect the loads for each hour, such as heating degree level, cooling degree level, day type (weekend, weekday or holiday), humidity, growth in load, and others. The hours are then grouped by the regression factor ranges to match the general characteristics of the load. This regression results in dividing each season into hour ranges for each 24 hour period that can be independently compared to determine their separate characteristics of energy performance in the population. The EVP will then perform all power and independent variable calculations by phase values, by season, by hourly ranges in all combinations of EEDS, ESS, EUS, and EUDs to calculate the energy changes due to modifications in the energy systems.
Additional features, advantages, and embodiments of the disclosure may be set forth or apparent from consideration of the detailed description and drawings. Moreover, it is to be understood that both the foregoing summary of the disclosure and the following detailed description are exemplary and intended to provide further explanation without limiting the scope of the disclosure as claimed.
BRIEF DESCRIPTION OF THE DRAWINGS
The accompanying drawings, which are included to provide a further understanding of the disclosure, are incorporated in and constitute a part of this specification, illustrate embodiments of the disclosure and together with the detailed description serve to explain the principles of the disclosure. No attempt is made to show structural details of the disclosure in more detail than may be necessary for a fundamental understanding of the disclosure and the various ways in which it may be practiced. In the drawings:
FIG. 1 shows an example of an EEDS made up of an electricity generation and distribution system connected to customer loads, according to principles of the disclosure;
FIG. 2 shows an example of a voltage control and conservation (VCC) system being measured at the ESS meter point and the EUS made up of Advanced Metering Infrastructure (AMI) measuring Voltage and Energy, according to the principles of the disclosure;
FIG. 3 shows an example of an Energy Validation Process (EVP) according to principles of the disclosure;
FIG. 4 shows an example of an Energy Validation Process (EVP) data base structure according to principles of the disclosure;
FIG. 5 shows an example of general outlier analysis to determine population measurements that are outside of normal operation, according to principles of the disclosure;
FIG. 6 shows an example of voltage outlier analysis to determine if independent variables such as voltage measurements are outside of normal operation, according to principles of the disclosure;
FIG. 7 shows examples of graphs of a voltage histograms of “OFF to ON” comparisons for determining the characteristics of the independent variables, according to principles of the disclosure;
FIG. 8 shows examples of graphs of sample points by weather and season in the “ON” and “OFF” conditions to view the characteristics of the weather and seasonal shifts in each sample and sample pair;
FIG. 9 shows an example of the high level pairing process for matching the weather, day type, and humidity for a population sample, according to the principles of the disclosure;
FIG. 10 shows an example of the results of breaking the load data into groups by season and by hourly groups with similar characteristics, according to the principles of the disclosure;
FIG. 11 shows an example of a process map of the optimal pairing process, according to the principles of the disclosure;
FIG. 12 shows an example of a histogram of the data pairing process to determine the CVR factor for the EEDS, according to principles of the disclosure;
FIG. 13 shows an example of an application of a paired test analysis process determining the change in usage per customer. The top histogram represents the pairing results and the bottom scatter plot demonstrates the results of the pairing values, according to principles of the disclosure;
FIG. 14 shows examples of histograms of the data pairing process to determine the CVR factor for the EEDS, one with a control EEDS to remove other independent variables, and one without the control EEDS, according to principles of the disclosure;
FIG. 15 shows an example of a summary chart for the data shown in previous Figures on CVR factor and Energy savings per customer, according to principles of the disclosure;
FIG. 16 shows an example of a pairing process meeting filter criteria according to principles of the disclosure;
FIG. 17 shows an example of a scatterplot of the paired population according to principles of the disclosure; and
FIG. 18 shows an example of the histogram of the data from an example CVR factor pairing calculation according to principles of the disclosure.
The present disclosure is further described in the detailed description that follows.
DETAILED DESCRIPTION OF THE DISCLOSURE
The disclosure and the various features and advantageous details thereof are explained more fully with reference to the non-limiting embodiments and examples that are described and/or illustrated in the accompanying drawings and detailed in the following description. It should be noted that the features illustrated in the drawings are not necessarily drawn to scale, and features of one embodiment may be employed with other embodiments as the skilled artisan would recognize, even if not explicitly stated herein. Descriptions of well-known components and processing techniques may be omitted so as to not unnecessarily obscure the embodiments of the disclosure. The examples used herein are intended merely to facilitate an understanding of ways in which the disclosure may be practiced and to further enable those of skill in the art to practice the embodiments of the disclosure. Accordingly, the examples and embodiments herein should not be construed as limiting the scope of the disclosure. Moreover, it is noted that like reference numerals represent similar parts throughout the several views of the drawings.
A “computer”, as used in this disclosure, means any machine, device, circuit, component, or module, or any system of machines, devices, circuits, components, modules, or the like, which are capable of manipulating data according to one or more instructions, such as, for example, without limitation, a processor, a microprocessor, a central processing unit, a general purpose computer, a super computer, a personal computer, a laptop computer, a palmtop computer, a notebook computer, a desktop computer, a workstation computer, a server, or the like, or an array of processors, microprocessors, central processing units, general purpose computers, super computers, personal computers, laptop computers, palmtop computers, notebook computers, desktop computers, workstation computers, servers, or the like.
A “server”, as used in this disclosure, means any combination of software and/or hardware, including at least one application and/or at least one computer to perform services for connected clients as part of a client-server architecture. The at least one server application may include, but is not limited to, for example, an application program that can accept connections to service requests from clients by sending back responses to the clients. The server may be configured to run the at least one application, often under heavy workloads, unattended, for extended periods of time with minimal human direction. The server may include a plurality of computers configured, with the at least one application being divided among the computers depending upon the workload. For example, under light loading, the at least one application can run on a single computer. However, under heavy loading, multiple computers may be required to run the at least one application. The server, or any if its computers, may also be used as a workstation.
A “database”, as used in this disclosure, means any combination of software and/or hardware, including at least one application and/or at least one computer. The database may include a structured collection of records or data organized according to a database model, such as, for example, but not limited to at least one of a relational model, a hierarchical model, a network model or the like. The database may include a database management system application (DBMS) as is known in the art. At least one application may include, but is not limited to, for example, an application program that can accept connections to service requests from clients by sending back responses to the clients. The database may be configured to run the at least one application, often under heavy workloads, unattended, for extended periods of time with minimal human direction.
A “communication link”, as used in this disclosure, means a wired and/or wireless medium that conveys data or information between at least two points. The wired or wireless medium may include, for example, a metallic conductor link, a radio frequency (RF) communication link, an Infrared (IR) communication link, an optical communication link, or the like, without limitation. The RF communication link may include, for example, WiFi, WiMAX, IEEE 802.11, DECT, 0G, 1G, 2G, 3G or 4G cellular standards, Bluetooth, and the like.
The terms “including”, “comprising” and variations thereof, as used in this disclosure, mean “including, but not limited to”, unless expressly specified otherwise.
The terms “a”, “an”, and “the”, as used in this disclosure, means “one or more”, unless expressly specified otherwise.
Devices that are in communication with each other need not be in continuous communication with each other, unless expressly specified otherwise. In addition, devices that are in communication with each other may communicate directly or indirectly through one or more intermediaries.
Although process steps, method steps, algorithms, or the like, may be described in a sequential order, such processes, methods and algorithms may be configured to work in alternate orders. In other words, any sequence or order of steps that may be described does not necessarily indicate a requirement that the steps be performed in that order. The steps of the processes, methods or algorithms described herein may be performed in any order practical. Further, some steps may be performed simultaneously.
When a single device or article is described herein, it will be readily apparent that more than one device or article may be used in place of a single device or article. Similarly, where more than one device or article is described herein, it will be readily apparent that a single device or article may be used in place of the more than one device or article. The functionality or the features of a device may be alternatively embodied by one or more other devices which are not explicitly described as having such functionality or features.
A “computer-readable medium”, as used in this disclosure, means any medium that participates in providing data (for example, instructions) which may be read by a computer. Such a medium may take many forms, including non-volatile media, volatile media, and transmission media. Non-volatile media may include, for example, optical or magnetic disks and other persistent memory. Volatile media may include dynamic random access memory (DRAM). Transmission media may include coaxial cables, copper wire and fiber optics, including the wires that comprise a system bus coupled to the processor. Transmission media may include or convey acoustic waves, light waves and electromagnetic emissions, such as those generated during radio frequency (RF) and infrared (IR) data communications. Common forms of computer-readable media include, for example, a floppy disk, a flexible disk, hard disk, magnetic tape, any other magnetic medium, a CD-ROM, DVD, any other optical medium, punch cards, paper tape, any other physical medium with patterns of holes, a RAM, a PROM, an EPROM, a FLASH-EEPROM, any other memory chip or cartridge, a carrier wave as described hereinafter, or any other medium from which a computer can read.
Various forms of computer readable media may be involved in carrying sequences of instructions to a computer. For example, sequences of instruction (i) may be delivered from a RAM to a processor, (ii) may be carried over a wireless transmission medium, and/or (iii) may be formatted according to numerous formats, standards or protocols, including, for example, WiFi, WiMAX, IEEE 802.11, DECT, 0G, 1G, 2G, 3G or 4G cellular standards, Bluetooth, or the like.
According to one non-limiting example of the disclosure, a voltage control and conservation (VCC) system 200 is provided (shown in FIG. 2) and the EVP is being used to monitor the change in EEDS energy from the VCC. The VCC, which includes three subsystems, including an energy delivery (ED) system 300, an energy control (EC) system 400 and an energy regulation (ER) system 500. The VCC system 200 is configured to monitor energy usage at the ED system 300 and determine one or more energy delivery parameters at the EC system (or voltage controller) 400. The EC system 400 may then provide the one or more energy delivery parameters CED to the ER system 500 to adjust the energy delivered to a plurality of users for maximum energy conservation. The energy validation process (EVP) system 600 monitors through communications link 610 all metered energy flow and determines the change in energy resulting from a change in voltage control at the ER system. The EVP system 600 also reads weather data information through a communication link 620 from an appropriate weather station 640 to execute the EVP process 630.
The VCC system 200 is also configured to monitor via communication link 610 energy change data from EVP system 600 and determine one or more energy delivery parameters at the EC system (or voltage controller) 400. The EC system 400 may then provide the one or more energy delivery parameters CED to the ER system 500 to adjust the energy delivered to a plurality of users for maximum energy conservation. Similarly, the EC system 400 may use the energy change data to control the electric energy delivery system 700 in other ways. For example, components of the EEDS 700 may be modified, adjusted, added or deleted, including the addition of capacitor banks, modification of voltage regulators, changes to end-user equipment to modify customer efficiency, and other control actions.
The VCC system 200 may be integrated into, for example, an existing load curtailment plan of an electrical power supply system. The electrical power supply system may include an emergency voltage reduction plan, which may be activated when one or more predetermined events are triggered. The predetermined events may include, for example, an emergency, an overheating of electrical conductors, when the electrical power output from the transformer exceeds, for example, 80% of its power rating, or the like. The VCC system 200 is configured to yield to the load curtailment plan when the one or more predetermined events are triggered, allowing the load curtailment plan to be executed to reduce the voltage of the electrical power supplied to the plurality of users.
FIG. 1 is similar to FIG. 1 of US publication 2013/0030591, with overlays that show an example of an EEDS 700 system, including an EUS system 900 and an ESS system 800 based on the electricity generation and distribution system 100, according to principles of the disclosure. The electricity generation and distribution system 100 includes an electrical power generating station 110, a generating step-up transformer 120, a substation 130, a plurality of step-down transformers 140, 165, 167, and users 150, 160. The electrical power generating station 110 generates electrical power that is supplied to the step-up transformer 120. The step-up transformer steps-up the voltage of the electrical power and supplies the stepped-up electrical power to an electrical transmission media 125. The ESS 800 includes the station 110, the step-up transformer 120, the substation 130, the step-down transformers 140, 165, 167, the ER 500 as described herein, and the electrical transmission media, including media 125, for transmitting the power from the station 110 to users 150, 160. The EUS 900 includes the ED 300 system as described herein, and a number of energy usage devices (EUD) 920 that may be consumers of power, or loads, including customer equipment and the like.
As seen in FIG. 1, the electrical transmission media may include wire conductors, which may be carried above ground by, for example, utility poles 127 and/or underground by, for example, shielded conductors (not shown). The electrical power is supplied from the step-up transformer 120 to the substation 130 as electrical power EIn(t), where the electrical power EIn in MegaWatts (MW) may vary as a function of time t. The substation 130 converts the received electrical power EIn(t) to ESupply(t) and supplies the converted electrical power ESupply(t) to the plurality of users 150, 160. The substation 130 may adjustably transform the voltage component VIn(t) of the received electrical power EIn(t) by, for example, stepping-down the voltage before supplying the electrical power ESupply(t) to the users 150, 160. The electrical power ESupply(t) supplied from the substation 130 may be received by the step-down transformers 140, 165, 167 and supplied to the users 150, 160 through a transmission medium 142, 162, such as, for example, but not limited to, underground electrical conductors (and/or above ground electrical conductors).
Each of the users 150, 160 may include an Advanced Meter Infrastructure (AMI) 155, 169. The AMI 155, 169 may be coupled to a Regional Operations Center (ROC) 180. The ROC 180 may be coupled to the AMI 155, 169, by means of a plurality of communication links 175, 184, 188, a network 170 and/or a wireless communication system 190. The wireless communication system 190 may include, but is not limited to, for example, an RF transceiver, a satellite transceiver, and/or the like.
The network 170 may include, for example, at least one of the Internet, a local area network (LAN), a wide area network (WAN), a metropolitan area network (MAN), a personal area network (PAN), a campus area network, a corporate area network, the electrical transmission media 125, 135 and transformers 140, 165, 167, a global area network (GAN), a broadband area network (BAN), or the like, any of which may be configured to communicate data via a wireless and/or a wired communication medium. The network 170 may be configured to include a network topology such as, for example, a ring, a mesh, a line, a tree, a star, a bus, a full connection, or the like.
The AMI 155, 169 may include any one or more of the following: A smart meter; a network interface (for example, a WAN interface, or the like); firmware; software; hardware; and the like. The smart meter may be configured to determine any one or more of the following: kilo-Watt-hours (kWh) delivered; kWh received; kWh delivered plus kWh received; kWh delivered minus kWh received; interval data; demand data; voltage; current; phase; and the like. If the smart meter is a three phase meter, then the low phase voltage may be used in the average calculation, or the values for each phase may be used independently. If the meter is a single phase meter, then the single voltage component will be averaged.
The AMI 155, 169 may further include one or more collectors (shown in FIG. 2) configured to collect smart meter data from one or more smart meters tasked with, for example, measuring and reporting electric power delivery and consumption at one or more of the users 150, 160. Alternatively (or additionally), the one or more collectors may be located external to the users 150, 160, such as, for example, in a housing holding the step-down transformers 140, 165, 167. Each of the collectors may be configured to communicate with the ROC 180.
VCC System 200
FIG. 2 shows an example of the VCC system 200 with the EVP system 600 monitoring the change in energy resulting from the VCC controlling the EEDS in the more efficient lower 5% band of voltage, according to principles of the disclosure. The VCC system 200 includes the ED system 300, the EC system 400 and the ER system 500, each of which is shown as a broken-line ellipse. The VCC system 200 is configured to monitor energy usage at the ED system 300. The ED system 300 monitors energy usage at one or more users 150, 160 (shown in FIG. 1) and sends energy usage information to the EC system 400. The EC system 400 processes the energy usage information and generates one or more energy delivery parameters CED, which it sends to the ER system 500. The ER system 500 receives the one or more energy delivery parameters CED and adjusts the electrical power ESupply(t) supplied to the users 150, 160 based on the received energy delivery parameters CED. The EVP system 600 receives the weather data and the energy usage data and calculates the energy usage improvement from the VCC.
The VCC system 200 minimizes power system losses, reduces user energy consumption and provides precise user voltage control. The VCC system 200 may include a closed loop process control application that uses user voltage data provided by the ED system 300 to control, for example, a voltage set point VSP on a distribution circuit (not shown) within the ER system 500. That is, the VCC system 200 may control the voltages VSupply(t) of the electrical power ESupply(t) supplied to the users 150, 160, by adjusting the voltage set point VSP of the distribution circuit in the ER system 500, which may include, for example, one or more load tap changing (LTC) transformers, one or more voltage regulators, or other voltage controlling equipment to maintain a tighter band of operation of the voltages VDelivered(t) of the electric power EDelivered(t) delivered to the users 150, 160, to lower power losses and facilitate efficient use of electrical power EDelivered(t) at the user locations 150 or 160.
The VCC system 200 controls or adjusts the voltage VSupply(t) of the electrical power ESupply(t) supplied from the EC system 500 based on smart meter data, which includes measured voltage VMeter(t) data from the users 150, 160 in the ED system 300, and based on validation data from the EVP system 600. The VCC system 200 may adjust the voltage set point VSP at the substation or line regulator level in the ER system 500 by, for example, adjusting the LTC transformer (not shown), circuit regulators (not shown), or the like, to maintain the user voltages VMeter(t) in a target voltage band VBand-n, which al may include a safe nominal operating range.
The VCC system 200 is configured to maintain the electrical power EDelivered(t) delivered to the users 150, 160 within one or more voltage bands VBand-n. For example, the energy may be delivered in two or more voltage bands VBand-n substantially simultaneously, where the two or more voltage bands may be substantially the same or different. The value VBand-n may be determined by the following expression [1]:
V Band-n =V SP +ΔV  [1]
where VBand-n is a range of voltages, n is a positive integer greater than zero corresponding to the number of voltage bands VBand that may be handled at substantially the same time, VSP is the voltage set point value and ΔV is a voltage deviation range.
For example, the VCC system 200 may maintain the electrical power EDelivered(t) delivered to the users 150, 160 within a band VBand-1 equal to, for example, 111V to 129V for rural applications, where VSP is set to 120V and ΔV is set to a deviation of seven-and-one-half percent (+/−7.5%). Similarly, the VCC system 200 may maintain the electrical power EDelivered(t) delivered to the users 150, 160 within a band VBand-2 equal to, for example, 114V to 126V for urban applications, where VSP is set to 120V and ΔV is set to a deviation of five (+/−5%).
The VCC system 200 may maintain the electrical power EDelivered(t) delivered to the users 150, 160 at any voltage band VBand-n usable by the users 150, 160, by determining appropriate values for VSP and ΔV. In this regard, the values VSP and ΔV may be determined by the EC system 400 based on the energy usage information for users 150, 160, received from the ED system 300.
The EC system 400 may send the VSP and ΔV values to the ER system 500 as energy delivery parameters CED, which may also include the value VBand-n. The ER system 500 may then control and maintain the voltage VDelivered(t) of the electrical power EDelivered(t) delivered to the users 150, 160, within the voltage band VBand-n. The energy delivery parameters CED may further include, for example, load-tap-changer (LTC) control commands.
The EVP system 600 may further measure and validate energy savings by comparing energy usage by the users 150, 160 before a change in the voltage set point value VSP (or voltage band VBand-n) to the energy usage by the users 150, 160 after a change in the voltage set point value VSP (or voltage band VBand-n), according to principles of the disclosure. These measurements and validations may be used to determine the effect in overall energy savings by, for example, lowering the voltage VDelivered(t) of the electrical power EDelivered(t) delivered to the users 150, 160, and to determine optimal delivery voltage bands VBand-n for the energy power EDelivered(t) delivered to the users 150, 160.
ER System 500
The ER system 500 may communicate with the ED system 300 and/or EC system 400 by means of the network 170. The ER system 500 is coupled to the network 170 and the EC system 400 by means of communication links 510 and 430, respectively. The EC system 500 is also coupled to the ED system 300 by means of the power lines 340, which may include communication links.
The ER system 500 includes a substation 530 which receives the electrical power supply EIn(t) from, for example, the power generating station 110 (shown in FIG. 1) on a line 520. The electrical power EIn(t) includes a voltage VIn(t) component and a current IIn(t) component. The substation 530 adjustably transforms the received electrical power Eat) to, for example, reduce (or step-down) the voltage component Vat) of the electrical power EIn(t) to a voltage value VSupply(t) of the electrical power ESupply(t) supplied to the plurality of smart meters 330 on the power supply lines 340.
The substation 530 may include a transformer (not shown), such as, for example, a load tap change (LTC) transformer. In this regard, the substation 530 may further include an automatic tap changer mechanism (not shown), which is configured to automatically change the taps on the LTC transformer. The tap changer mechanism may change the taps on the LTC transformer either on-load (on-load tap changer, or OLTC) or off-load, or both. The tap changer mechanism may be motor driven and computer controlled. The substation 530 may also include a buck/boost transformer to adjust and maximize the power factor of the electrical power EDelivered(t) supplied to the users on power supply lines 340.
Additionally (or alternatively), the substation 530 may include one or more voltage regulators, or other voltage controlling equipment, as known by those having ordinary skill in the art, that may be controlled to maintain the output the voltage component VSupply(t) of the electrical power ESupply(t) at a predetermined voltage value or within a predetermined range of voltage values.
The substation 530 receives the energy delivery parameters CED from the EC system 400 on the communication link 430. The energy delivery parameters CED may include, for example, load tap coefficients when an LTC transformer is used to step-down the input voltage component VIn(t) of the electrical power EIn(t) to the voltage component VSupply(t) of the electrical power ESupply(t) supplied to the ED system 300. In this regard, the load tap coefficients may be used by the ER system 500 to keep the voltage component VSupply(t) on the low-voltage side of the LTC transformer at a predetermined voltage value or within a predetermined range of voltage values.
The LTC transformer may include, for example, seventeen or more steps (thirty-five or more available positions), each of which may be selected based on the received load tap coefficients. Each change in step may adjust the voltage component VSupply(t) on the low voltage side of the LTC transformer by as little as, for example, about five-sixteenths (0.3%), or less.
Alternatively, the LTC transformer may include fewer than seventeen steps. Similarly, each change in step of the LTC transformer may adjust the voltage component VSupply(t) on the low voltage side of the LTC transformer by more than, for example, about five-sixteenths (0.3%).
The voltage component VSupply(t) may be measured and monitored on the low voltage side of the LTC transformer by, for example, sampling or continuously measuring the voltage component VSupply(t) of the stepped-down electrical power ESupply(t) and storing the measured voltage component VSupply(t) values as a function of time t in a storage (not shown), such as, for example, a computer readable medium. The voltage component VSupply(t) may be monitored on, for example, a substation distribution bus, or the like. Further, the voltage component VSupply(t) may be measured at any point where measurements could be made for the transmission or distribution systems in the ER system 500.
Similarly, the voltage component VIn(t) of the electrical power EIn(t) input to the high voltage side of the LTC transformer may be measured and monitored. Further, the current component ISupply(t) of the stepped-down electrical power ESupply(t) and the current component IIn(t) of the electrical power EIn(t) may also be measured and monitored. In this regard, a phase difference φIn(t) between the voltage VIn(t) and current IIn(t) components of the electrical power EIn(t) may be determined and monitored. Similarly, a phase difference φSupply(t) between the voltage VSupply(t) and current ISupply(t) components of the electrical energy supply ESupply(t) may be determined and monitored.
The ER system 500 may provide electrical energy supply status information to the EC system 400 on the communication links 430 or 510. The electrical energy supply information may include the monitored voltage component VSupply(t). The electrical energy supply information may further include the voltage component VIn(t), current components IIn(t), ISupply(t), and/or phase difference values φIn(t), φSupply(t), as a function of time t. The electrical energy supply status information may also include, for example, the load rating of the LTC transformer.
The electrical energy supply status information may be provided to the EC system 400 at periodic intervals of time, such as, for example, every second, 5 sec., 10 sec., 30 sec., 60 sec., 120 sec., 600 sec., or any other value within the scope and spirit of the disclosure, as determined by one having ordinary skill in the art. The periodic intervals of time may be set by the EC system 400 or the ER system 500. Alternatively, the electrical energy supply status information may be provided to the EC system 400 or ER system 500 intermittently.
Further, the electrical energy supply status information may be forwarded to the EC system 400 in response to a request by the EC system 400, or when a predetermined event is detected. The predetermined event may include, for example, when the voltage component VSupply(t) changes by an amount greater (or less) than a defined threshold value VSupplyThreshold (for example, 130V) over a predetermined interval of time, a temperature of one or more components in the ER system 500 exceeds a defined temperature threshold, or the like.
ED System 300
The ED system 300 includes a plurality of smart meters 330. The ED system 300 may further include at least one collector 350, which is optional. The ED system 300 may be coupled to the network 170 by means of a communication link 310. The collector 350 may be coupled to the plurality of smart meters 330 by means of a communication link 320. The smart meters 330 may be coupled to the ER system 500 by means of one or more power supply lines 340, which may also include communication links.
Each smart meter 330 is configured to measure, store and report energy usage data by the associated users 150, 160 (shown in FIG. 1). Each smart meter 330 is further configured to measure and determine energy usage at the users 150, 160, including the voltage component VMeter(t) and current component IMeter(t) of the electrical power EMeter(t) used by the users 150, 160, as a function of time. The smart meters 330 may measure the voltage component VMeter(t) and current component IMeter(t) of the electrical power EMeter(t) at discrete times ts, where s is a sampling period, such as, for example, s=5 sec., 10 sec., 30 sec., 60 sec., 300 sec., 600 sec., or more. For example, the smart meters 330 may measure energy usage every, for example, minute (t60 sec), five minutes (t300 sec), ten minutes (t600 sec), or more, or at time intervals variably set by the smart meter 330 (for example, using a random number generator).
The smart meters 330 may average the measured voltage VMeter(t) and/or IMeter(t) values over predetermined time intervals (for example, 5 min., 10 min., 30 min., or more). The smart meters 330 may store the measured electrical power usage EMeter(t) including the measured voltage component VMeter(t) and/or current component IMeter(t) as smart meter data in a local (or remote) storage (not shown), such as, for example, a computer readable medium.
Each smart meter 330 is also capable of operating in a “report-by-exception” mode for any voltage VMeter(t), current IMeter(t), or energy usage EMeter(t) that falls outside of a target component band. The target component band may include, a target voltage band, a target current band, or a target energy usage band. In the “report-by-exception” mode, the smart meter 330 may sua sponte initiate communication and send smart meter data to the EC system 400. The “report-by-exception” mode may be used to reconfigure the smart meters 330 used to represent, for example, the lowest voltages on the circuit as required by changing system conditions.
The smart meter data may be periodically provided to the collector 350 by means of the communication links 320. Additionally, the smart meters 330 may provide the smart meter data in response to a smart meter data request signal received from the collector 350 on the communication links 320.
Alternatively (or additionally), the smart meter data may be periodically provided directly to the EC system 400 (for example, the MAS 460) from the plurality of smart meters, by means of, for example, communication links 320, 410 and network 170. In this regard, the collector 350 may be bypassed, or eliminated from the ED system 300. Furthermore, the smart meters 330 may provide the smart meter data directly to the EC system 400 in response to a smart meter data request signal received from the EC system 400. In the absence of the collector 350, the EC system (for example, the MAS 460) may carry out the functionality of the collector 350 described herein.
The request signal may include, for example, a query (or read) signal and a smart meter identification signal that identifies the particular smart meter 330 from which smart meter data is sought. The smart meter data may include the following information for each smart meter 130, including, for example, kilo-Watt-hours (kWh) delivered data, kWh received data, kWh delivered plus kWh received data, kWh delivered minus kWh received data, voltage level data, current level data, phase angle between voltage and current, kVar data, time interval data, demand data, and the like.
Additionally, the smart meters 330 may send the smart meter data to the meter automation system server MAS 460. The smart meter data may be sent to the MAS 460 periodically according to a predetermined schedule or upon request from the MAS 460.
The collector 350 is configured to receive the smart meter data from each of the plurality of smart meters 330 via the communication links 320. The collector 350 stores the received smart meter data in a local storage (not shown), such as, for example, a computer readable medium. The collector 350 compiles the received smart meter data into a collector data. In this regard, the received smart meter data may be aggregated into the collector data based on, for example, a geographic zone in which the smart meters 330 are located, a particular time band (or range) during which the smart meter data was collected, a subset of smart meters 330 identified in a collector control signal, and the like. In compiling the received smart meter data, the collector 350 may average the voltage component VMeter(t) values received in the smart meter data from all (or a subset of all) of the smart meters 330.
The EC system 400 is able to select or alter a subset of all of the smart meters 330 to be monitored for predetermined time intervals, which may include for example 15 minute intervals. It is noted that the predetermined time intervals may be shorter or longer than 15 minutes. The subset of all of the smart meters 330 is selectable and can be altered by the EC system 400 as needed to maintain minimum level control of the voltage VSupply(t) supplied to the smart meters 330.
The collector 350 may also average the electrical power EMeter(t) values received in the smart meter data from all (or a subset of all) of the smart meters 330. The compiled collector data may be provided by the collector 350 to the EC system 400 by means of the communication link 310 and network 170. For example, the collector 350 may send the compiled collector data to the MAS 460 (or ROC 490) in the EC system 400.
The collector 350 is configured to receive collector control signals over the network 170 and communication link 310 from the EC system 400. Based on the received collector control signals, the collector 350 is further configured to select particular ones of the plurality of smart meters 330 and query the meters for smart meter data by sending a smart meter data request signal to the selected smart meters 330. The collector 350 may then collect the smart meter data that it receives from the selected smart meters 330 in response to the queries. The selectable smart meters 330 may include any one or more of the plurality of smart meters 330. The collector control signals may include, for example, an identification of the smart meters 330 to be queried (or read), time(s) at which the identified smart meters 330 are to measure the VMeter(t), IMeter(t), EMeter(t) and/or φMeter(t) (φMeter(t) is the phase difference between the voltage VMeter(t) and current IMeter(t) components of the electrical power EMeter(t) measured at the identified smart meter 330), energy usage information since the last reading from the identified smart meter 330, and the like. The collector 350 may then compile and send the compiled collector data to the MAS 460 (and/or ROC 490) in the EC system 400.
EC System 400
The EC system 400 may communicate with the ED system 300 and/or ER system 500 by means of the network 170. The EC system 400 is coupled to the network 170 by means of one or more communication links 410. The EC system 400 may also communicate directly with the ER system 500 by means of a communication link 430.
The EC system 400 includes the MAS 460, a database (DB) 470, a distribution management system (DMS) 480, and a regional operation center (ROC) 490. The ROC 490 may include a computer (ROC computer) 495, a server (not shown) and a database (not shown). The MAS 460 may be coupled to the DB 470 and DMS 480 by means of communication links 420 and 440, respectively. The DMS 480 may be coupled to the ROC 490 and ER SYSTEM 500 by means of the communication link 430. The database 470 may be located at the same location as (for example, proximate to, or within) the MAS 460, or at a remote location that may be accessible via, for example, the network 170.
The EC system 400 is configured to de-select, from the subset of monitored smart meters 330, a smart meter 330 that the EC system 400 previously selected to monitor, and select the smart meter 330 that is outside of the subset of monitored smart meters 330, but which is operating in the report-by-exception mode. The EC system 400 may carry out this change after receiving the sua sponte smart meter data from the non-selected smart meter 330. In this regard, the EC system 400 may remove or terminate a connection to the de-selected smart meter 330 and create a new connection to the newly selected smart meter 330 operating in the report-by-exception mode. The EC system 400 is further configured to select any one or more of the plurality of smart meters 330 from which it receives smart meter data comprising, for example, the lowest measured voltage component VMeter(t) and generate an energy delivery parameter CED based on the smart meter data received from the smart meter(s) 330 that provide the lowest measured voltage component VMeter(t).
The MAS 460 may include a computer (not shown) that is configured to receive the collector data from the collector 350, which includes smart meter data collected from a selected subset (or all) of the smart meters 330. The MAS 460 is further configured to retrieve and forward smart meter data to the ROC 490 in response to queries received from the ROC 490. The MAS 460 may store the collector data, including smart meter data in a local storage and/or in the DB 470.
The DMS 480 may include a computer that is configured to receive the electrical energy supply status information from the substation 530. The DMS 480 is further configured to retrieve and forward measured voltage component VMeter(t) values and electrical power EMeter(t) values in response to queries received from the ROC 490. The DMS 480 may be further configured to retrieve and forward measured current component IMeter(t) values in response to queries received from the ROC 490. The DMS 480 also may be further configured to retrieve all “report-by-exception” voltages VMeter(t) from the smart meters 330 operating in the “report-by-exception” mode and designate the voltages VMeter(t) as one of the control points to be continuously read at predetermined times (for example, every 15 minutes, or less (or more), or at varying times). The “report-by-exception voltages VMeter(t) may be used to control the EC 500 set points.
The DB 470 may include a plurality of relational databases (not shown). The DB 470 includes a large number of records that include historical data for each smart meter 330, each collector 350, each substation 530, and the geographic area(s) (including latitude, longitude, and altitude) where the smart meters 330, collectors 350, and substations 530 are located.
For instance, the DB 470 may include any one or more of the following information for each smart meter 330, including: a geographic location (including latitude, longitude, and altitude); a smart meter identification number; an account number; an account name; a billing address; a telephone number; a smart meter type, including model and serial number; a date when the smart meter was first placed into use; a time stamp of when the smart meter was last read (or queried); the smart meter data received at the time of the last reading; a schedule of when the smart meter is to be read (or queried), including the types of information that are to be read; and the like.
The historical smart meter data may include, for example, the electrical power EMeter(t) used by the particular smart meter 330, as a function of time. Time t may be measured in, for example, discrete intervals at which the electrical power EMeter magnitude (kWh) of the received electrical power EMeter(t) is measured or determined at the smart meter 330. The historical smart meter data includes a measured voltage component VMeter(t) of the electrical energy EMeter(t) received at the smart meter 330. The historical smart meter data may further include a measured current component IMeter(t) and/or phase difference φMeter(t) of the electrical power EMeter(t) received at the smart meter 330.
As noted earlier, the voltage component VMeter(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, one minute, five minutes, ten minutes, fifteen minutes, or the like. The current component IMeter(t) and/or the received electrical power EMeter(t) values may also be measured at substantially the same times as the voltage component VMeter(t).
Given the low cost of memory, the DB 470 may include historical data from the very beginning of when the smart meter data was first collected from the smart meters 330 through to the most recent smart meter data received from the smart meter 330 s.
The DB 470 may include a time value associated with each measured voltage component VMeter(t), current component IMeter(t) phase component φMeter(t) and/or electrical power EMeter(t), which may include a timestamp value generated at the smart meter 330. The timestamp value may include, for example, a year, a month, a day, an hour, a minute, a second, and a fraction of a second. Alternatively, the timestamp may be a coded value which may be decoded to determine a year, a month, a day, an hour, a minute, a second, and a fraction of a second, using, for example, a look up table. The ROC 490 and/or smart meters 330 may be configured to receive, for example, a WWVB atomic clock signal transmitted by the U.S. National Institute of Standards and Technology (NIST), or the like and synchronize its internal clock (not shown) to the WWVB atomic clock signal.
The historical data in the DB 470 may further include historical collector data associated with each collector 350. The historical collector data may include any one or more of the following information, including, for example: the particular smart meters 330 associated with each collector 350; the geographic location (including latitude, longitude, and altitude) of each collector 350; a collector type, including model and serial number; a date when the collector 350 was first placed into use; a time stamp of when collector data was last received from the collector 350; the collector data that was received; a schedule of when the collector 350 is expected to send collector data, including the types of information that are to be sent; and the like.
The historical collector data may further include, for example, an external temperature value TCollector(t) measured outside of each collector 350 at time t. The historical collector data may further include, for example, any one or more of the following for each collector 350: an atmospheric pressure value PCollector(t) measured proximate the collector 350 at time t; a humidity value HCollector(t) measured proximate the collector 350 at time t; a wind vector value WCollector(t) measured proximate the collector 350 at time t, including direction and magnitude of the measured wind; a solar irradiant value LCollector(t) (kW/m2) measured proximate the collector 350 at time t; and the like.
The historical data in the DB 470 may further include historical substation data associated with each substation 530. The historical substation data may include any one or more of the following information, including, for example: the identifications of the particular smart meters 330 supplied with electrical energy ESupply(t) by the substation 530; the geographic location (including latitude, longitude, and altitude) of the substation 530; the number of distribution circuits; the number of transformers; a transformer type of each transformer, including model, serial number and maximum Megavolt Ampere (MVA) rating; the number of voltage regulators; a voltage regulator type of each voltage regulator, including model and serial number; a time stamp of when substation data was last received from the substation 530; the substation data that was received; a schedule of when the substation 530 is expected to provide electrical energy supply status information, including the types of information that are to be provided; and the like.
The historical substation data may include, for example, the electrical power ESupply(t) supplied to each particular smart meter 330, where ESupply(t) is measured or determined at the output of the substation 530. The historical substation data includes a measured voltage component VSupply(t) of the supplied electrical power ESupply(t), which may be measured, for example, on the distribution bus (not shown) from the transformer. The historical substation data may further include a measured current component ISupply(t) of the supplied electrical power ESupply(t). As noted earlier, the voltage component VSupply(t), the current component ISupply(t), and/or the electrical power ESupply(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, a minute, five minutes, ten minutes, or the like. The historical substation data may further include a phase difference value φSupply(t) between the voltage VSupply(t) and current ISupply(t) signals of the electrical power ESupply(t), which may be used to determine the power factor of the electrical power ESupply(t) supplied to the smart meters 330.
The historical substation data may further include, for example, the electrical power EIn(t) received on the line 520 at the input of the substation 530, where the electrical power EIn(t) is measured or determined at the input of the substation 530. The historical substation data may include a measured voltage component VIn(t) of the received electrical power EIn(t), which may be measured, for example, at the input of the transformer. The historical substation data may further include a measured current component IIn(t) of the received electrical power EIn(t). As noted earlier, the voltage component VIn(t), the current component IIn(t), and/or the electrical power EIn(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, a minute, five minutes, ten minutes, or the like. The historical substation data may further include a phase difference φIn(t) between the voltage component VIn(t) and current component IIn(t) of the electrical power EIn(t). The power factor of the electrical power EIn(t) may be determined based on the phase difference φIn(t).
According to an aspect of the disclosure, the EC system 400 may save aggregated kW data at the substation level, voltage data at the substation level, and weather data to compare to energy usage per smart meter 330 to determine the energy savings from the VCC system 200, and using linear regression to remove the effects of weather, load growth, economic effects, and the like, from the calculation.
In the VCC system 200, control may be initiated from, for example, the ROC computer 495. In this regard, a control screen 305 may be displayed on the ROC computer 495, as shown, for example, in FIG. 3 of US publication 2013/0030591. The control screen 305 may correspond to data for a particular substation 530 (for example, the TRABUE SUBSTATION) in the ER system 500. The ROC computer 495 can control and override (if necessary), for example, the substation 530 load tap changing transformer based on, for example, the smart meter data received from the ED system 300 for the users 150, 160. The ED system 300 may determine the voltages of the electrical power supplied to the user locations 150, 160, at predetermined (or variable) intervals, such as, e.g., on average each 15 minutes, while maintaining the voltages within required voltage limits.
For system security, the substation 530 may be controlled through the direct communication link 430 from the ROC 490 and/or DMS 480, including transmission of data through communication link 430 to and from the ER 500, EUS 300 and EVP 600.
Furthermore, an operator can initiate a voltage control program on the ROC computer 490, overriding the controls, if necessary, and monitoring a time it takes to read the user voltages VMeter(t) being used for control of, for example, the substation LTC transformer (not shown) in the ER system 500.
FIG. 3 shows the energy validation process 600 for determining the amount of conservation in energy per customer realized by operating the VCC system in FIGS. 1-2. The process is started 601 and the data the ON and OFF periods is loaded 602 by the process manager. The next step is to collect 603 the hourly voltage and power (MW) data from the metering data points on the VCC system from the DMS 480 which may be part of a supervisory control and data acquisition (SCADA) type of industrial control system. Next the corresponding weather data is collected 604 for the same hourly conditions. The data is processed 605, 606, 607, 608 to improve its quality using filters and analysis techniques to eliminate outliers that could incorrectly affect the results, as describe further below. If hourly pairing is to be done the hourly groups are determined 609 using the linear regression techniques. The next major step is to determine 611, 612, 613, 614, 615, 616, 617 the optimal pairing of the samples, as described further below.
FIG. 4 shows an example of the database structure where the initial data for analysis is kept. This relational data base allows for fast processing of the data and marking of data that is not to be used because of the anomalies. The efficient storage of the data for continued analysis is useful to provide the evaluation performance for the EVP.
FIG. 5 shows an example of an application of the data quality reviews of the data before processing. Using the database the values are scanned for out of range levels in all categories, such as the zero MW readings 622 and the very low voltage readings 623. These are identified and removed before processing. Second, it shows repeated values, such as the repeated voltage reading of 122.331 volts in the data box 621, that are indicative of bad measurements and would severely degrade the calculation of the energy change. These are also removed from the future calculations. Known anomalies, including missing records due to daylight savings time changes 624, are removed as well.
FIG. 6 shows an example of a frequency plot of voltage at hourly intervals. It is expected that most of the data will follow a normalized form when analyzed. This makes it easier to spot poor quality data in the outlier data as shown here. Data are reviewed using the frequency plots and the outliers are reviewed for consistency with normal operating conditions on the system. The outliers, such as voltages 623, can be eliminated if they fall outside of predetermined bands. This is an example of analysis applied to all of the variables.
FIG. 7 shows an example of histogram plots of the “OFF” to “ON” data comparisons for both voltage and MW. As is seen on the top two diagrams the voltage for the “ON” state has a significantly wider deviation that the “OFF” data. This is also a concern when the standard deviation of the comparison data does not match. Data sets having out of range or non-matching standard deviations may be filtered out. In contrast the MW data had very consistent standard deviations and very little differences in the “ON” to “OFF” state population characteristics.
FIG. 8 shows an example of the comparison of scatterplots of the “OFF” (black points on the scatterplots) to “ON” (red points on the scatterplots) populations by season and by group. These plots are useful for reviews of the level of the sampling across the entire performance levels. As can be seen from these examples there are a number of areas 624, 625 where there are no “ON” samples for large areas of the “OFF” performance levels. This means that more sampling will be needed to accurately represent these conservation performance zones. The quick review of the scatterplots can give a significant knowledge of the sample size and adequacy for this type of measurement.
FIG. 9 shows an example of the high level pairing process which is based on a well-established statistical comparison technique called paired t. The purpose of this calculation is to compare two samples of data to determine the average shift in a variable mean from one sample set to the other. Documentation of the details of paired t analysis can be found in a number of standard statistic publications and is readily available in standard software packages. FIG. 9 is a high level description of the process being applied to the Substation 530 Transformer and ED 300 circuit MW and Voltage data. The value being calculated is the CVR factor which establishes the ratio of (a) the percent power (watts) change from sample 1 (P1) to sample 2 (P2) to (b) the percent voltage (volts) change from sample 1 (V1) to sample 2 (V2). The CVR factor=((P1−P2)/P1)/((V1−V2)/V1). Sample 1 is take from the MW and Voltage data at the meter when the CVR control system is “OFF” and Sample 2 is taken from the data when CVR is “ON”. A larger CVR factor indicates more power savings from reduction in voltage, with common observed CVR factors for some CVR systems being observed in the range of about 0.2 to 1.2.
Sets of samples are paired using the rules of FIG. 9. Records 1 and 2 in FIG. 9 are for Samples 1 and 2 respectively. For Samples 1 and 2: the immediately upstream transformer (TX #1) must be the same (=); the Status (e.g., whether CVR is OFF or ON) must be different (< >), the Day Type (e.g., workday, weekend or holiday) must be equal (=); Cooling degree days and heating degree days (CDD/HDD) should each be matched within plus or minus one degree day (±1 DD), and relative humidity should be matched within plus or minus five percent (±5% RH). This matching of two samples from the “OFF” and “ON” states creates one pair of samples. Once paired, the volts and power from the Samples 1 and 2 may be used for the CVR factor calculation. At least 30 of these pairs are required for the calculation of the average difference between the two sample sets to have statistical significance (about a 95% confidence level).
There are three features of the paired t analysis for the illustrated embodiment. First the paired samples are independent. This requires that for each sample taken from a data set, whether for sample 1 (OFF state) or sample 2 (ON state), the values from the sample can only be used and paired one time in the analysis. Once they are used, the samples are removed from the data sets to choose the next pair. The second feature is that the data sets are normal data sets. This is checked statistically for each analysis. Normality is checked using the Anderson-Darling normality test. Third, the number of paired t samples are greater than about 30 to be statistically significant. This calculation will be shown for each set of analysis. Once these three features are present, the paired t analysis is implemented and the average difference is determined within a confidence interval determined by the variation of the paired samples. The illustrated embodiment uses 95% confidence level for the CVR analysis.
FIG. 10 shows an example of a method used for decreasing the variation in the calculation by separating the samples into consistent groups. For the MW and Voltage data this is done by grouping the sample data into like hours that are consistent with each other. This may be done with a linear regression technique. Using linear regression, the consistency of the variables is checked. Samples taken in the same hour of the day (hours 0 through 23 in the heading of the table of FIG. 10) are grouped and are noted in the same column in FIG. 10. Sample hours that represent like data are determined by using the linear regression constants to check consistency between hours that are grouped together. In addition each data set is grouped into a seasonal grouping as well. The result of this grouping process is to first break the sample data up into the seasonal groups of winter, spring, summer and fall. Then using the linear regression break the hours for each seasonal day (0 to 23) into like groups for paired t testing. This technique will lessen the variation in the paired t calculation for average difference from one sample group to another. The table in FIG. 10 is an example of this type of process.
FIG. 11 shows the detailed pairing process for a multiple variable example of the VCC pairing both HDD/CDD along with humidity. The process creates a total list of possible matched pairs in all combinations. Each pair is scored based on a linear optimization method to weigh the independent variable appropriately based on its energy effect and use the linearization to form the optimal scoring for the pair including both independent variables of HDD/CDD and humidity using linear regression constants. For example, if the energy effect (e.g., change in CVR factor) for HDD/CDD is five times the energy effect for humidity, a difference in HDD/CDD between samples is weighted five times as much as the difference in humidity between samples.
Once this process is complete the list is reviewed for the best score. These are paired and removed from the pairing list. The process is repeated for each of the remaining pairs until all pairs have been optimally matched for variables within the tolerance levels as shown in the process diagram of FIG. 11. In this way the pairing is optimized to the population giving the best accuracy for the data available, according to the illustrated embodiment with the given criteria.
FIG. 12 shows an example of the histogram of the data from the CVR factor pairing calculation. It is noted that the pairing is normalized and fits the characteristics of the t-distribution. With this information the data can be used to evaluate the range of average values of the CVR factor for the circuit during the time period the data was taken. This data can be calculated for a data set of 30 or more and will produce an accurate representation of the range of the CVR factor. Each data set requires a one-day time period. Normally the 95% confidence interval is used to determine a usable range for the CVR factor. This statistical factor is specifically for the circuit under evaluation and provides ongoing evaluation of the performance of the circuit down to a minimum of 30 data sets and thus a 30-day interval.
FIG. 13 shows an example of the histogram and the scatterplot of the energy saving per customer over the interval from the same paired t analysis. The top graph is a measure of the kW/customer change and has the same type of normalized characteristic that is compatible with the t-distribution confidence interval analysis. The scatterplot of the paired population plotted in an “OFF” to “ON” state give a quick intuitive evaluation of the paired data. In general if the majority of the pairs are below the red line the VCC system is improving the conservation, if they are equally spaced on either side of the line it is not having any effect and if they are on average above the line it is having the reverse effect. In this case it is easy to see that the samples are clearly showing improvement in conservation of energy.
FIG. 14 shows an alternative example of the CVR factor analysis for another circuit. The graph on the right of FIG. 14. demonstrates the characteristics for a measurement done without the control circuit being used to compensate for the other independent variables. The results show a non-normal population with a much higher CVR savings. In this case there was a substantial decrease in load because of lower electricity demand due to the downturn in the economy, thus making the CVR factor look abnormally high. The graph on the left of FIG. 14 is with the control circuit and uses the circuit to remove the non-normal effects of the negative economic growth. The CVR factor using this control circuit does decrease but the normality becomes very strong and the data is back in a normal range for the VCC control system to be the only independent variable controlling the effects.
FIG. 15 shows an example of the final calculations on both the CVR factor and the savings in energy derive from the optimal pairing of the VCC system energy. This results in a direct calculation of the capacity of the circuit to reduce energy as stated in the CVR factor. This capacity is its ability to conserve energy by reducing voltage in the lower operating band. The VCC system executes this type of control and the EVP independently calculates the capacity of the circuit to continue to conserve as other modifications to the voltage performance are implemented.
FIG. 15 also shows an example of the final calculations for energy savings during the measurement time under study. This energy savings is a continuous reporting of the circuit's ability to continue to sustain the conservation savings that were calculated for the VCC system. This ability to continuously track the performance instead of having to do repeated one time testing of the circuit to estimate the performance represents a major step forward in the technology. Existing systems are based on one time tests that greatly reduce the efficiency performance just to estimate the CVR factor and the energy saving performance. In addition they must be repeated on regular intervals to determine if the saving is being sustained. This EVP system provides a major step forward in being able to generate near metered savings without reducing the efficiency of the VCC system.
In one example embodiment a paired t approach blends a CVR modification ON-OFF approach with filters that leverage the benefits of a regression analysis. This blended approach may provide meaningful results in a shorter period of time than an unblended approach and allows users of the blended approach to have little to no down time after beginning an implementation of a CVR program. The end result is a CVR factor which represents the percent change in energy for a percent change in voltage. This CVR factor can then be used with hourly load and voltage data to sum energy savings during a CVR deployment.
One goal of a measurement and verification analysis is a clean view of performance with and without voltage reduction in service. In one example, a system can be configured to calculate savings at a CVR node (e.g. a substation transformer or circuit) level using substation electrical energy supplied (MW) and bus voltage (line voltage) to compare energy usage before (OFF) and after (ON) voltage reduction. A CVR node may include, for example, a substation transformer or circuit or other location where CVR is to be calculated, which can be at any location within a power generation, transmission, and distribution system.
In one embodiment, the data may be from the same season to avoid skewing due to load changes between heating, cooling and other factors. The data analysis can be performed across time (e.g. summer 2013 vs. summer 2014) or within a season (e.g. July 2014 vs. August 2014), or it can accommodate a structured day on—day off test run for a minimum time period, for example about two weeks.
In one example embodiment, a process can include: inputting ON-OFF data; applying filters, such as filtering for weather and outliers; creating pairs and generating a CVR factor; and using the CVR factor to calculate savings.
Further to the description discussing FIGS. 8 and 10, in another example embodiment, data collected from the “ON” state and data collected from the “OFF” state can be from the same season to avoid skewing due to load changes between heating, cooling, and other seasonal factors. The data can be analyzed across time, for example summer 2013 versus summer 2014; within a season, for example July 2014 versus August 2014; or across a structured day on-day off test for a minimum time period, for example about two weeks.
In an example embodiment using an hourly pairing, hours in an ON period can be compared to hours in an OFF period, for example every hour in an ON period can be compared to every hour in an OFF period. In one example embodiment, once all filters, which will be discussed in more detail below, have been applied, a pool of acceptable pairs is generated. As will be discussed further below, an outlier filter may be applied before or after a pool of acceptable pairs is generated. The pairs can be rank ordered based on one or more criteria, for example quality of temperature match; quality of humidity match; hour type match; and any other custom filter, and can be followed by a tie-breaker criteria, which in one example embodiment can be time elapsed between records. Once records have been rank-ordered, a selection of pairs, for example the best pairs, can be chosen until a desired number of pairs have been matched, for example all possible pairs have been matched.
Filters can be used to refine an ON-OFF pairing process. One or more filters can be used on a set of data to achieve paired records and may function as a modified regression method for pairing records. In one example, these filters ensure that the primary difference between records is the voltage change. In one embodiment, one or more filters can be used on a set of data to achieve paired records within specific tolerances, or nearly identical. In one example, this method compares ON and OFF records that are nearly identical in terms of weather and therefore in terms of expected load.
The following are example filters that can be employed alone or in combination with any number of the other filters: a Temperature Filter; a first prior time filter, for example, a prior 6 Hours Filter that averages the temperature, or other measurement, over the prior 6 hours; a second prior time filter, for example, a prior 72 Hours Filter that averages the temperature, or other measurement, over the prior 72 hours; a Humidity Filter; a 168-Hourly Index Filter; a MW Change Filter; a Voltage Change Filter; a Custom Filter; and an Outlier Filter. Any suitable combination of filters may be chosen. FIG. 16 shows an example embodiment employing a Temperature Filter, a Prior 6 Hours Filter, a Prior 72 Hours Filter, a Humidity Filter, a 168-Hourly Index Filter, a MW Change Filter; a Voltage Change Filter; a Custom Filter, and an Outlier Filter, along with example specific tolerances of each filter.
In one example embodiment of the Temperature Filter, the Temperature Filter may exclude records that are not within a specified temperature difference. Any suitable temperature difference may be used. FIG. 16 shows one example embodiment where the temperature difference is limited to 1 degree Fahrenheit.
In one example embodiment of the Prior 6 Hour Filter, the Prior 6 Hour Filter may exclude records that are not within a specified average temperature difference for the 6 hours immediately preceding the time when the record was taken. Any suitable average temperature difference may be used. FIG. 16 shows one example embodiment where the average temperature difference is limited to 1 degree Fahrenheit.
In one example embodiment of the Prior 72 Hour Filter, the Prior 72 Hour Filter may exclude records that are not within a specified average temperature difference for the 72 hours immediately preceding the time when the record was taken. Any suitable average temperature difference may be used. FIG. 16 shows one example embodiment where the average temperature difference is limited to 1 degree Fahrenheit.
In one example embodiment of the Relative Humidity Filter, the Relative Humidity Filter may exclude records that are not within a specified humidity difference. Any suitable humidity difference may be used. In one example embodiment, the difference is limited to less than or equal to about two percentage points. In another example embodiment, the difference is limited to less than or equal to about five percentage points. FIG. 16 shows one example embodiment where the difference is limited to less than or equal to one percentage point.
In one example embodiment of the 168 Hourly Index Filter, the 168 Hourly Index Filter can be analyzed with a statistical regression to determine the loading impact of an hour, so that similar hours can be paired. For the 168 Hourly Index, each hour in a seven day time period is given an index number (i.e., from 1 to 168) corresponding to the chronological occurrence of that hour. In an example embodiment using hourly pairing, it is preferable for the hours to have similar loading characteristics. The 168 hours in a particular week are analyzed with a statistical regression to determine the loading impact of the hours independent of the temperature and humidity impacts, so that similar hours can be paired. It can be appreciated that other suitable index windows may be employed. FIG. 16 shows an example embodiment where the 168 Hourly Index is configured to filter records that are not within one index number.
In one example embodiment of the MW Filter, the MW Filter may exclude data points that demonstrate large changes in energy consumption. A certain reduction is expected, but large swings may indicate that external forces are at contributing. Any suitable percent change may be used. In one example embodiment, the percent change can be limited to less than or equal to 3%. FIG. 16 shows another example embodiment where the percent change can be limited to less than or equal to 5%.
In one example embodiment of the Voltage Filter, the Voltage Filter may ensure that the two records do not have voltages within a specified voltage range. Any suitable voltage range may be used. FIG. 16 shows one example embodiment where the records must be at least about 1 volt apart.
In one example embodiment of the Custom Filter, the Custom Filter may allow users to create a custom filter of their choice that may be unique to their service territory. Any suitable custom filter may be used. FIG. 16 shows one example embodiment where the custom filter is set to a linear value correlation.
In one example embodiment of the Outlier Filter, the Outlier Filter may be applied with the other filters or can be applied after the records have been paired, and can be used to analyze the resulting pairs for outliers. Any suitable outlier filtering process may be used. In one example embodiment, the Outlier Filter uses Median Absolute Deviation (MAD) to filter out resulting pairs that are extreme outliers. FIG. 16 shows one example embodiment using MAD, wherein the Outlier Filter is limited to a MAD of plus or minus 5.
Further to the description discussing FIG. 13, FIG. 17 shows an example of a scatterplot of the paired population. Each dot represents a paired set of hours at their respective loads. The paired population plotted in an “OFF” to “ON” state gives a quick intuitive evaluation of the paired data. The data points below the line indicate the ON record had a lower load than the OFF record in the pair, indicating a load reduction for the matched pair. In general, if the majority of the pairs are below the line, the VCC system is improving the conservation, if they are equally spaced on either side of the line it is not having any effect, and if they are on average above the line it is having the reverse effect. In the example embodiment of FIG. 17, the scatterplot shows that in most cases shown, the ON record had lower load than its corresponding OFF record, showing an improvement in conservation of energy.
Further to the description of FIG. 12, FIG. 18 shows an example of the histogram of the data from the CVR factor pairing calculation. It is noted that the pairing is normalized and fits the characteristics of the t-distribution. With this information the data can be used to evaluate the range of average values of the CVR factor for the circuit during the time period the data was taken. The mean CVR factor across all pairs can be used as the CVR factor for the time period analyzed. In one example embodiment, this data can be calculated for a data set of 30 or more and will produce an accurate representation of the range of the CVR factor. Normally the 95% confidence interval is used to determine a usable range for the CVR factor. This statistical factor is specifically for the circuit under evaluation and provides ongoing evaluation of the performance of the circuit down to a minimum of 30 data sets.
Once a CVR factor has been established, the savings calculation becomes a function of comparing the actual hourly voltages to a baseline voltage. The resulting percent reduction in voltage, combined with the CVR factor, gives a percent reduction in energy usage. In one configuration, the system may use the hourly energy savings computation to sum all hours and give a monthly or seasonal energy savings value. The resulting electric power control system produces a statistically accurate, repeatable energy savings measurement while preserving energy savings.
In one example embodiment using a paired t approach, a process for calculating savings at a CVR node may include the following steps: collecting data when a modification to the electric power system is in the OFF state; collecting data when a modification to the electrical power system is in the ON state; collecting other common ambient and/or weather condition data on for each ON state and OFF state data point, said other common ambient and/or weather conditions comprising one or more of temperature, heating degree, cooling degree, humidity, prior 6 hour average, prior 72 hour average, 168 hourly index, electrical energy, volts, custom conditions, and outliers; applying filters; creating pairs; generating a CVR factor; and using the CVR factor with hourly load and voltage data to sum energy savings during the CVR deployment.
While the disclosure has been described in terms of exemplary embodiments, those skilled in the art will recognize that the disclosure can be practiced with modifications in the spirit and scope of the appended claims. These examples are merely illustrative and are not meant to be an exhaustive list of all possible designs, embodiments, applications or modifications of the disclosure.

Claims (30)

What is claimed as new and desired to be protected by Letters Patent of the United States is:
1. A control system for an electric power grid configured to supply electric power from a supply point to a plurality of consumption locations, the system comprising:
a plurality of sensors, wherein each sensor is located at a respective one of a plurality of distribution locations on the distribution grid at or between the supply point and at least one of the plurality of consumption locations, and wherein each sensor is configured to sense a component of the supplied electric power received at the respective distribution location and to generate measurement data based on the sensed component of the power;
a controller configured to receive measurement data from the plurality of sensors, and to operate the electric power grid in a modification-on state or in a modification-off state; wherein the controller generates an energy delivery parameter based on the measurement data;
a component adjusting device configured to adjust a component of the electric power grid in response to the energy delivery parameter;
wherein the controller is configured to determine, using an energy validation process, the change in energy characteristics between the modification-on state and the modification-off state, using a paired comparison, wherein the paired comparison includes a pairing process and the pairing process includes applying at least one filter selected from the group consisting of:
a temperature filter configured to not pair records that are not within a predetermined temperature difference,
a prior time filter configured to not pair records that are not within a predetermined average temperature difference for a predetermined prior time period immediately preceding the time when the records were taken,
a relative humidity filter configured to not pair records that are not within a predetermined humidity difference,
an interval index filter configured to order sub-interval periods by a loading impact of each sub-interval period and to not pair records that are not within a predetermined index offset value,
MW filter configured to not pair records that not within a predetermined MW difference,
a voltage filter configured to not pair records that not within a predetermined voltage difference,
a linear value correlation filter configured to not pair records that not within a predetermined linear correlation factor, and
an outlier filter configured to exclude paired records greater than a predetermined Median Absolute Deviation (MAD).
2. The system of claim 1, wherein the controller generates an energy delivery parameter based on the measurement data when the controller is in the modification-on state, but not when the controller is in the modification-off state.
3. The system of claim 1, wherein the component of the supplied electric power is measured by the sensors on an interval basis.
4. The system of claim 1, wherein the component of the supplied electric power is voltage.
5. The system of claim 4, wherein the component of the electric power grid adjusting device comprises: a load tap change transformer that adjusts the voltage of the electric power supplied at the supply point based on a load tap change coefficient; or a voltage regulator that adjusts the voltage of the electric power supplied at the supply point based on the energy delivery parameter.
6. The system of claim 5, wherein the load tap change transformer is located at a substation and at least one sensor is located at the substation.
7. The system of claim 1, wherein the modification is conservation voltage reduction (CVR).
8. The system of claim 7, wherein the change in energy characteristic is determined at a a CVR node.
9. The system of claim 1, wherein the energy characteristic is the conservation voltage reduction factor.
10. The system of claim 1, wherein the energy characteristic is the energy savings.
11. The system of claim 1, wherein the paired comparison includes a pairing process for selecting pairs of data to compare.
12. The system of claim 11, wherein the paired comparison includes a paired t measurement.
13. The system of claim 1, wherein the paired comparison comprises an additional process that breaks the paired comparison process into measurements by season and uses linear regression constants to determine the blocks of hours where consistent loads exist and paired t comparisons can be calculated within predetermined limits.
14. The system of claim 1, wherein the predetermined prior time of the prior time filter is about six hours.
15. The system of claim 1, wherein the predetermined prior time of the prior time filter is about seventy two hours.
16. The system of claim 1, wherein the at least one filter includes the outlier filter and the outlier filter is configured to exclude paired records greater than a predetermined Median Absolute Deviation (MAD).
17. The system of claim 1, wherein the controller is configured to use the paired t p-factor to eliminate data having values outside of corresponding predetermined normalized ranges of values to determine measurement accuracy.
18. The system of claim 1, wherein the controller is configured to determining the change in energy characteristic based on a first variable.
19. The system of claim 18, wherein the first variable is season, grouped hour, or customer type.
20. The system of claim 18, wherein the controller is configured to provide a second pairing variable that is secondary to the first pairing variable, to pair the first variable values to the closest modification-off to modification-on values, and determining a weighed scoring of the pairs based on the relative slopes of the linear relationship between the first and second respective variables.
21. The system of claim 1, wherein the controller is configured to exclude data that is affected by non-efficiency variables.
22. A method for controlling electrical power supplied to a plurality of distribution locations located at or between a supply point and at least one consumption location, each of the plurality of distribution locations including at least one sensor configured to sense a voltage of the supplied electric power received at the respective distribution location and generate measurement data based on the sensed voltage, the method comprising:
controlling the electric power grid in a modification-on state or in a modification-off state; wherein a controller generates an energy delivery parameter based on the measurement data when the controller is in the modification-on state, but not when the controller is in the modification-off state;
operating an component adjusting device configured to adjust a component of the electric power grid in response to the energy delivery parameter;
measuring the component of the supplied electric power with the sensors on an interval basis using an energy validation process, and determining the change in energy characteristics between the voltage conservation-voltage-reduction-on state and the conservation-voltage-reduction-off being using a paired comparison, wherein the paired comparison includes a pairing process and the pairing process includes applying at least one filter selected from the group consisting of:
a temperature filter configured to not pair records that are not within a predetermined temperature difference,
a prior time filter configured to not pair records that are not within a predetermined average temperature difference for a predetermined prior time period immediately preceding the time when the records were taken,
a relative humidity filter configured to not pair records that are not within a predetermined humidity difference,
an interval index filter configured to order sub-interval periods by a loading impact of each sub-interval period and to not pair records that are not within a predetermined index offset value,
a MW filter configured to not pair records that not within a predetermined MW difference,
a voltage filter configured to not pair records that not within a predetermined voltage difference,
a linear value correlation filter configured to not pair records that not within a predetermined linear correlation factor, and
an outlier filter configured to exclude paired records greater than a predetermined Median Absolute Deviation (MAD).
23. The method of claim 22, wherein the component of the supplied electric power is voltage.
24. The method of claim 22, wherein the modification is conservation voltage reduction (CVR).
25. The method of claim 22, wherein the component of the electric power grid adjusting device comprises: a load tap change transformer that adjusts the voltage of the electric power supplied at the supply point based on a load tap change coefficient; or a voltage regulator that adjusts the voltage of the electric power supplied at the supply point based on the energy delivery parameter.
26. The method of claim 22 wherein the energy characteristic is the conservation voltage reduction factor.
27. The method of claim 22, wherein the energy characteristic is the energy savings.
28. The method of claim 22, wherein the paired comparison includes a pairing process for selecting pairs of data to compare.
29. The method of claim 28, wherein the paired comparison includes a paired t measurement.
30. The method of claim 22, wherein the paired comparison comprises an additional process that breaks the paired comparison process into measurements by season and uses linear regression constants to determine the blocks of hours where consistent loads exist and paired t comparisons can be calculated accurately, within predetermined limits.
US15/009,016 2013-03-15 2016-01-28 Electric power system control with measurement of energy demand and energy efficiency Active US9847639B2 (en)

Priority Applications (4)

Application Number Priority Date Filing Date Title
US201361789085P true 2013-03-15 2013-03-15
US14/193,980 US9563218B2 (en) 2013-03-15 2014-02-28 Electric power system control with measurement of energy demand and energy efficiency using t-distributions
US201562109322P true 2015-01-29 2015-01-29
US15/009,016 US9847639B2 (en) 2013-03-15 2016-01-28 Electric power system control with measurement of energy demand and energy efficiency

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US15/009,016 US9847639B2 (en) 2013-03-15 2016-01-28 Electric power system control with measurement of energy demand and energy efficiency

Related Parent Applications (1)

Application Number Title Priority Date Filing Date
US14/193,980 Continuation-In-Part US9563218B2 (en) 2013-03-15 2014-02-28 Electric power system control with measurement of energy demand and energy efficiency using t-distributions

Publications (2)

Publication Number Publication Date
US20160164290A1 US20160164290A1 (en) 2016-06-09
US9847639B2 true US9847639B2 (en) 2017-12-19

Family

ID=56095191

Family Applications (1)

Application Number Title Priority Date Filing Date
US15/009,016 Active US9847639B2 (en) 2013-03-15 2016-01-28 Electric power system control with measurement of energy demand and energy efficiency

Country Status (1)

Country Link
US (1) US9847639B2 (en)

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9678520B2 (en) * 2013-03-15 2017-06-13 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using AMI-based data analysis
US9582020B2 (en) * 2013-03-15 2017-02-28 Dominion Resources, Inc. Maximizing of energy delivery system compatibility with voltage optimization using AMI-based data control and analysis
JP6677197B2 (en) * 2017-03-15 2020-04-08 オムロン株式会社 Harmonic detection system
CN107505884B (en) * 2017-07-31 2021-03-12 新奥泛能网络科技股份有限公司 Diagnosis method of universal energy station equipment, cloud server and system

Citations (314)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3900842A (en) 1973-03-29 1975-08-19 Automated Technology Corp Remote automatic meter reading and control system
US3970898A (en) 1973-11-23 1976-07-20 Zellweger Uster Ag Method of automatically isolating a faulty section of a power line belonging to an electrical energy supply network, and arrangement for carrying out this method
US4054830A (en) 1974-03-25 1977-10-18 Landis Tool Company Regulated power supply
US4234904A (en) 1978-07-19 1980-11-18 Lgz Landis & Gyr Zug Ag Process and device for the protection of electrical energy supply systems controlled by means of audio-frequency
EP0020310A1 (en) 1979-05-28 1980-12-10 Arnaldo Spena A remote control direct electric load management system
US4291377A (en) 1978-11-13 1981-09-22 Lgz Landis & Gyr Zug Ag. Apparatus for measuring electrical power
US4302750A (en) 1979-08-03 1981-11-24 Compuguard Corporation Distribution automation system
US4307380A (en) 1977-05-17 1981-12-22 Lgz Landis & Gyr Zug Ag Transmitting signals over alternating current power networks
US4309655A (en) 1978-06-23 1982-01-05 Lgz Landis & Gyr Zug Ag Measuring transformer
US4310829A (en) 1978-04-27 1982-01-12 Lgz Landis & Gyr Zug Ag Transmitting device for communications equipment for generating a signal to be superimposed on an AC power supply network
JPS57148533A (en) 1981-03-10 1982-09-13 Tokyo Shibaura Electric Co Method of operating substation facility
US4356553A (en) 1978-12-01 1982-10-26 Lgz Landis & Gyr Zug Ag Method for the measuring of electrical power
US4361872A (en) 1977-12-29 1982-11-30 Lgz Landis & Gyr Zug Ag Measuring apparatus for determining the effective value of the power demand of an energy consumer over a period of calculation
US4365302A (en) 1981-01-14 1982-12-21 Westinghouse Electric Corp. High accuracy AC electric energy metering system
US4434400A (en) 1980-05-02 1984-02-28 Lgz Landis & Gyr Zug Ag Circuit for supervising an electronic electricity meter
US4450931A (en) 1981-03-09 1984-05-29 Ngk Insulators, Ltd. Structure for decreasing low frequency air vibration
US4513273A (en) 1983-03-02 1985-04-23 Lgz Landis & Gyr Zug Ag Transducer for current measurement
US4525668A (en) 1980-12-24 1985-06-25 Lgz Landis & Gyr Zug Ag System for measuring electrical output or energy
US4630220A (en) 1984-03-06 1986-12-16 Southern California Edison Company Voltage controller
US4686630A (en) 1984-09-27 1987-08-11 Process Systems, Inc. Load management control system and method
US4686752A (en) 1982-06-25 1987-08-18 Beckman Instruments, Inc. Method of forming slots in a material-retaining plate for a packed column reactor in an analytical instrument
US4695737A (en) 1986-03-19 1987-09-22 Southern California Edison Microcomputer controlled power regulator system and method
JPS63299722A (en) 1987-05-28 1988-12-07 Hitachi Ltd Voltage regulation relay
US4791520A (en) 1986-03-08 1988-12-13 Sachsenwerk Aktiengesellschaft Fault protection for a medium voltage transformer branch
US4843310A (en) 1985-06-15 1989-06-27 Lgz Landis & Gyr Zug Ag Electricity meter with arrangement for monitoring core saturation incidents
US4853620A (en) 1987-08-06 1989-08-01 Lgz Landis & Gyr Zug Ag Circuit arrangement comprising multiplier circuits to find the sum of electrical power outputs for application in multi-phase electricity meters
US4881027A (en) 1987-08-06 1989-11-14 Lgz Landis & Gyr Zug Ag Circuit arrangement comprising input circuits to find a power output sum for application in multi-phase electricity meters
US4887028A (en) 1987-09-21 1989-12-12 Landis & Gyr Metering, Inc. Watthour meter with isolation transformers having a feedback loop
US4894610A (en) 1985-09-14 1990-01-16 LOZ Landis & Gyr Zug AG Current-transformer arrangement for an electrostatic meter
US4896106A (en) 1987-09-21 1990-01-23 Landis & Gyr Metering, Inc. Watthour meter for wye connected systems
US5028862A (en) 1989-12-26 1991-07-02 Honeywell Inc. Voltage follower circuit for use in power level control circuits
US5032785A (en) 1989-03-31 1991-07-16 Landis & Gyr Betriebs Ag Arrangement for measuring an electrical power or energy
US5055766A (en) 1990-06-04 1991-10-08 Duke Power Company Voltage regulator compensation in power distribution circuits
US5066906A (en) 1989-09-22 1991-11-19 Landis & Gyr Metering, Inc. Time of use register for use with a utility meter
US5124624A (en) 1989-12-14 1992-06-23 Landis & Gyr Betriebs Ag Arrangement for electrical measurement
US5128855A (en) 1988-06-08 1992-07-07 Lgz Landis & Gyr Zug Ag Building automation system operating installation control and regulation arrangement
US5136233A (en) 1991-04-09 1992-08-04 Iowa-Illinois Gas And Electric Company Means and method for controlling elecrical transformer voltage regulating tapchangers
US5231347A (en) 1992-02-28 1993-07-27 Landis & Gyr Metering, Inc. Power factor matching in an AC power meter
US5249150A (en) 1990-05-03 1993-09-28 Landis & Gyr Betriebs Ag Process and circuit to determine estimates of the instantaneous value of parameters of at least one sinusoidal signal with constant and known frequency which is an additive component of a measuring signal
US5262715A (en) 1991-07-22 1993-11-16 Landis & Gyr Betriebs Ag Arrangement for the measurement of reactive power or reactive energy
US5270639A (en) 1989-09-22 1993-12-14 Landis & Gyr Metering, Inc. Time of use register for use with a utility meter
US5272462A (en) 1991-06-03 1993-12-21 Merlin Gerin Remote transmission device by on-line carrier currents designed for control and monitoring of an electrical power distribution system, notably medium voltage
US5298857A (en) 1992-04-06 1994-03-29 Landis & Gyr Metering, Inc. Electrical energy meter with a precision integrator for current measurement
US5343143A (en) 1992-02-11 1994-08-30 Landis & Gyr Metering, Inc. Shielded current sensing device for a watthour meter
US5422561A (en) 1992-11-23 1995-06-06 Southern California Edison Company Automated voltage and VAR control in power transmission and distribution networks
US5432507A (en) 1992-10-27 1995-07-11 Societa' Italiana Per Il Gas P.A. Method and network for operating a distribution network
US5466973A (en) 1992-04-29 1995-11-14 N.V. Geb Zuid-Holland West Delivery point voltage regulation in electric energy distribution networks
US5475867A (en) 1992-02-06 1995-12-12 Itron, Inc. Distributed supervisory control and data acquisition system
US5511108A (en) 1991-05-31 1996-04-23 Itronix Corporation Apparatus and method for performing and controlling testing of electrical equipment
RU2066084C1 (en) 1994-09-21 1996-08-27 Российский институт радионавигации и времени Device for control of electric load
US5552696A (en) 1994-02-18 1996-09-03 Siemens Energy & Automation, Inc. Multiple setpoint configuration in a voltage regulator controller
US5602750A (en) 1991-05-31 1997-02-11 Itronix Corporation Administrative computer and testing apparatus
US5604414A (en) 1994-09-15 1997-02-18 Landis & Gyr Energy Management Method and apparatus for adjusting overload compensation for a watthour meter
US5610394A (en) 1996-04-29 1997-03-11 Itron, Inc. Rotation monitor disturbance neutralization system
US5627759A (en) 1995-05-31 1997-05-06 Process Systems, Inc. Electrical energy meters having real-time power quality measurement and reporting capability
US5646512A (en) 1995-08-30 1997-07-08 Beckwith; Robert W. Multifunction adaptive controls for tapswitches and capacitors
US5673252A (en) 1990-02-15 1997-09-30 Itron, Inc. Communications protocol for remote data generating stations
US5736848A (en) 1994-09-05 1998-04-07 Landis & Gyr Technology Innovation Ag Analog-to-digital measurement and calibration system for electrical energy
WO1998026489A1 (en) 1996-12-09 1998-06-18 Target - Hi-Tech Electronics Ltd. APPARATUS FOR AND METHOD OF EVENLY DISTRIBUTING AN ELECTRICAL LOAD ACROSS AN n-PHASE POWER DISTRIBUTION NETWORK
JPH10164756A (en) 1996-11-28 1998-06-19 Hitachi Ltd Method and apparatus for controlling power system
US5903548A (en) 1996-12-19 1999-05-11 Itronix Corporation Portable electronic communications device having switchable LAN/WAN wireless communications features
US5918380A (en) 1997-09-17 1999-07-06 Itron, Inc. Time-of-use and demand metering in conditions of power outage
US5963146A (en) 1990-02-15 1999-10-05 Itron, Inc. Wide area communications network for remote data generating stations
US6006212A (en) 1997-09-17 1999-12-21 Itron, Inc. Time-of-use and demand metering in conditions of power outage with a mobile node
US6026355A (en) 1996-09-18 2000-02-15 Itron, Inc. Solid state watt-hour meter using GMR sensor
US6218995B1 (en) 1997-06-13 2001-04-17 Itron, Inc. Telemetry antenna system
US6333975B1 (en) 1998-03-03 2001-12-25 Itron, Inc. Method and system for reading intelligent utility meters
US6373236B1 (en) 1999-02-18 2002-04-16 Itron, Inc. Temperature compensated power detector
US20020109607A1 (en) 2000-07-21 2002-08-15 Itron, Inc. Spread spectrum meter reading system utilizing low-speed/high-power frequency hopping
JP2002247780A (en) 2001-02-20 2002-08-30 Mitsubishi Electric Corp Power quality control operation support system and power quality control operation support method
US20020128748A1 (en) 2000-12-15 2002-09-12 Alexander Krakovich Configurable switchgear system
US6555997B1 (en) 1998-09-15 2003-04-29 Landis+Gyr Ag Electricity meter and an input module for an electricity meter
US20030122686A1 (en) 1999-02-23 2003-07-03 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US6590376B1 (en) 1998-05-28 2003-07-08 Landis+Gyr Ag Method of deriving a frequency of a pulse signal from alternate sources and method of calibrating same
US6618684B1 (en) 2000-01-26 2003-09-09 Elster Electricity, Llc System and method for digitally compensating frequency and temperature induced errors in amplitude and phase shift in current sensing of electronic energy meters
US6628207B1 (en) 1997-12-24 2003-09-30 Elster Electricity, Llc Method and apparatus for detecting and reporting a power outage
US20030187550A1 (en) 2002-04-01 2003-10-02 Wilson Thomas L. Electrical power distribution control systems and processes
US6633823B2 (en) 2000-07-13 2003-10-14 Nxegen, Inc. System and method for monitoring and controlling energy usage
US6636893B1 (en) 1998-09-24 2003-10-21 Itron, Inc. Web bridged energy management system and method
US6650249B2 (en) 1998-05-01 2003-11-18 Elster Electricity, Llc Wireless area network communications module for utility meters
US6667692B2 (en) 2001-06-29 2003-12-23 Landis+Gyr Inc. Electrical utility meter having harmonic data templates for power quality alarm thresholds
US6684245B1 (en) 1997-04-08 2004-01-27 Elster Electricity, Llc Automatic meter reading system employing common broadcast command channel
US6700902B1 (en) 1998-10-19 2004-03-02 Elster Electricity, Llc Method and system for improving wireless data packet delivery
US6703823B1 (en) 1992-02-21 2004-03-09 Elster Electricity, Llc Method and apparatus for electronic meter testing
JP2004096906A (en) 2002-08-30 2004-03-25 E-Plat Co Ltd System and method for power management, cubicle arrangement, measuring apparatus, communication apparatus, distribution board, server for power management
US6738693B2 (en) 2000-12-20 2004-05-18 Landis+Gyr Inc. Multiple virtual meters in one physical meter
US6747446B1 (en) 1999-09-24 2004-06-08 Landis+Gyr Inc. Arrangement for providing external access to functionality switches in a utility meter
US6747981B2 (en) 1997-02-12 2004-06-08 Elster Electricity, Llc Remote access to electronic meters using a TCP/IP protocol suite
US20040119458A1 (en) 1999-01-27 2004-06-24 Elster Electricity, Llc Advanced instrument packaging for electronic energy meter
US6757628B1 (en) 1998-07-14 2004-06-29 Landis+Gyr Inc. Multi-level transformer and line loss compensator and method
US6756914B1 (en) 1999-11-12 2004-06-29 Itron, Inc. Low impedance encoder for a utility meter
US20040150575A1 (en) 2003-02-03 2004-08-05 Silver Spring Networks, Inc. Flush-mounted antenna and transmission system
US6773652B2 (en) 2002-10-02 2004-08-10 Elster Electricity, Llc Process for the manufacture of a cover system for an electrical-energy meter
US6798353B2 (en) 2002-04-24 2004-09-28 Itron Electricity Metering, Inc. Method of using flash memory for storing metering data
US20040192415A1 (en) 2003-03-25 2004-09-30 Silver Spring Networks, Inc. Wireless communication system
US6816538B2 (en) 2002-06-26 2004-11-09 Elster Electricity, Llc Frequency hopping spread spectrum decoder
US6815942B2 (en) 2001-09-25 2004-11-09 Landis+Gyr, Inc. Self-calibrating electricity meter
US20040222783A1 (en) 2002-06-27 2004-11-11 Elster Electricity, Llc Electrical-energy meter
US6832169B2 (en) 2002-01-29 2004-12-14 Hitachi, Ltd. Substation system
US6832135B2 (en) 2001-07-10 2004-12-14 Yingco Electronic Inc. System for remotely controlling energy distribution at local sites
US6847201B2 (en) 2001-01-29 2005-01-25 Landis+Gyr Ag Compensation circuit for the phase shift in electric meters for direct connection
US20050024235A1 (en) 2002-06-27 2005-02-03 Elster Electricity, Llc Dynamic self-configuring metering network
US6859742B2 (en) 2001-07-12 2005-02-22 Landis+Gyr Inc. Redundant precision time keeping for utility meters
US6868293B1 (en) 2000-09-28 2005-03-15 Itron, Inc. System and method for energy usage curtailment
US6867707B1 (en) 2002-04-24 2005-03-15 Elster Electricity, Llc Automated on-site meter registration confirmation using a portable, wireless computing device
US6873144B2 (en) 2000-04-07 2005-03-29 Landis+Gyr Inc. Electronic meter having random access memory with passive nonvolatility
US6882137B1 (en) 2002-12-05 2005-04-19 Landis+Gyr, Inc. Enhanced fault protection in electricity meter
US6885185B1 (en) 1998-12-01 2005-04-26 Itron Electricity Metering, Inc. Modular meter configuration and methodology
US20050090995A1 (en) 2003-10-27 2005-04-28 Itron Inc. Distributed asset optimization (DAO) system and method
US6888876B1 (en) 2001-12-21 2005-05-03 Elster Electricity, Llc Frequency hopping spread spectrum communications system
US6892144B2 (en) 2001-09-25 2005-05-10 Landis+Gyr, Inc. Arrangement for providing sensor calibration information in a modular utility meter
US20050110480A1 (en) 2003-07-01 2005-05-26 Itron Electricity Metering, Inc. System and method for acquiring voltages and measuring voltage into an electrical service using a non-active current transformer
US6900737B1 (en) 1997-02-12 2005-05-31 Elster Electricity, Llc Remote access to electronic meters using the short message service
US20050119841A1 (en) 2003-11-06 2005-06-02 Landisinc. Method of timing demand and time-of-use functionality with external clock source
US20050119930A1 (en) 2003-10-21 2005-06-02 Itron, Inc. Combined scheduling and management of work orders, such as for utility meter reading and utility servicing events
US20050125104A1 (en) * 2003-12-05 2005-06-09 Wilson Thomas L. Electrical power distribution control systems and processes
US6906637B2 (en) 2001-10-29 2005-06-14 Landis + Gyr, Inc. Utility disconnect controller
US6906507B2 (en) 1993-03-26 2005-06-14 Itron Electricity Metering, Inc. Electronic revenue meter with automatic service sensing
US6940268B2 (en) 1992-02-21 2005-09-06 Elster Electricity, Llc Apparatus for metering at least one type of electrical power over a predetermined range of service voltages
US6947854B2 (en) 2000-02-29 2005-09-20 Quadlogic Controls Corporation System and method for on-line monitoring and billing of power consumption
US20050212689A1 (en) 2001-09-25 2005-09-29 Landis+Gyr, Inc. Utility meter power arrangements and methods
US20050218873A1 (en) 2004-04-05 2005-10-06 Elster Electricity, Llc Switching regulator with reduced conducted emissions
US20050240314A1 (en) 2004-04-27 2005-10-27 Martinez Edwin A Method and apparatus for controlling and monitoring electrical power consumption
US20050237047A1 (en) 2002-12-05 2005-10-27 Landisinc. Enhanced fault protection in electricity meter
US20050251403A1 (en) 2004-05-10 2005-11-10 Elster Electricity, Llc. Mesh AMR network interconnecting to TCP/IP wireless mesh network
US20050251401A1 (en) 2004-05-10 2005-11-10 Elster Electricity, Llc. Mesh AMR network interconnecting to mesh Wi-Fi network
US20050278440A1 (en) 2004-06-15 2005-12-15 Elster Electricity, Llc. System and method of visualizing network layout and performance characteristics in a wireless network
US20060001415A1 (en) 2004-04-22 2006-01-05 Landisinc. Utility meter having programmable pulse output
US6988043B1 (en) 1999-10-21 2006-01-17 Landis+Gyr Inc. External transformer correction in an electricity meter
US20060012935A1 (en) 2004-07-13 2006-01-19 Elster Electricity, Llc Transient protector circuit for multi-phase energized power supplies
US20060038548A1 (en) 2004-08-17 2006-02-23 Elster Electricity, Llc. High voltage regulator for an electric meter power supply
US7005844B2 (en) 2001-02-07 2006-02-28 Landis & Gyr Ag Measuring circuit arrangement for electricity meters for direct connection
US20060044157A1 (en) 2004-08-27 2006-03-02 Itron Electricity Metering, Inc. Firmware power cycle routine
US20060044851A1 (en) 2004-08-25 2006-03-02 Itron Electricity Metering, Inc. Resistor dropper power supply with surge protection
US7009379B2 (en) 2002-09-12 2006-03-07 Landis & Gyr, Inc. Electricity meter with power supply load management
US20060055610A1 (en) 2004-08-27 2006-03-16 Itron Electricity Metering, Inc. Embedded antenna and filter apparatus and methodology
US20060056493A1 (en) 2000-08-01 2006-03-16 Itron, Inc. Frequency hopping spread spectrum system with high sensitivity tracking and synchronization for frequency unstable signals
US7020178B2 (en) 2002-06-26 2006-03-28 Elster Electricity, Llc Microprocessor decoder frequency hopping spread spectrum communications receiver
US20060074601A1 (en) 2004-10-01 2006-04-06 Itron, Inc. Endpoint location file format, such as for use in mapping endpoints in a utility meter reading system
US20060071810A1 (en) 2004-09-24 2006-04-06 Elster Electricity, Llc. System for automatically enforcing a demand reset in a fixed network of electricity meters
US20060071812A1 (en) 2002-06-28 2006-04-06 Elster Electricity Llc Data collector for an automated meter reading system
US20060074556A1 (en) 2004-10-01 2006-04-06 Itron, Inc. Utility data collection system employing location data receiver, such as a dual USB port GPS receiver
US20060085147A1 (en) 2004-10-20 2006-04-20 Itron, Inc. Automated utility meter reading system with variable bandwidth receiver
US7046682B2 (en) 1997-02-12 2006-05-16 Elster Electricity, Llc. Network-enabled, extensible metering system
US20060114121A1 (en) 2004-10-29 2006-06-01 Itron, Inc. Integrated meter module and utility metering system
US20060126255A1 (en) 2000-12-26 2006-06-15 Landisinc. Excessive surge protection method and apparatus
US20060145890A1 (en) 2001-09-14 2006-07-06 Landisinc. Utility meter with external signal-powered transceiver
US20060158348A1 (en) 2005-01-14 2006-07-20 Landisinc. Utility meter having RF protection
US7084783B1 (en) 2002-08-13 2006-08-01 Elster Electricity, Llc Electronic meter with enhanced thermally managed communications systems and methods
US20060168804A1 (en) 2004-03-31 2006-08-03 Elster Electricity, Llc Method for providing an electrical connection
JP2006208047A (en) 2005-01-25 2006-08-10 Muroran Institute Of Technology Multipoint simultaneous measurement data processor and processing method
US7091878B2 (en) 2001-02-28 2006-08-15 Landis+Gyr, Inc. Electrical service disconnect having tamper detection
US20060195229A1 (en) * 2002-04-01 2006-08-31 Programmable Control Services, Inc. Electrical power distribution control systems and processes
US20060206433A1 (en) 2005-03-11 2006-09-14 Elster Electricity, Llc. Secure and authenticated delivery of data from an automated meter reading system
US7109882B2 (en) 2004-02-19 2006-09-19 Itron, Inc. Utility endpoint communication scheme, such as for sequencing the order of meter reading communications for electric, gas, and water utility meters.
US20060217936A1 (en) 2005-03-22 2006-09-28 Elster Electricity Llc Using a fixed network wireless data collection system to improve utility responsiveness to power outages
US7116243B2 (en) 2003-09-05 2006-10-03 Itron, Inc. System and method for automatic meter reading with mobile configuration
US20060224335A1 (en) 2005-03-29 2006-10-05 Elster Electricity, Llc Collecting interval data from a relative time battery powered automated meter reading devices
US7119698B2 (en) 2003-10-16 2006-10-10 Itron, Inc. Consumptive leak detection system
US7149605B2 (en) 2003-06-13 2006-12-12 Battelle Memorial Institute Electrical power distribution control methods, electrical energy demand monitoring methods, and power management devices
US7154938B2 (en) 2002-12-31 2006-12-26 Itron, Inc. RF communications system utilizing digital modulation to transmit and receive data
US7161455B2 (en) 2003-02-03 2007-01-09 Landis + Gyr Inc. Method and arrangement for securing sensors in an electricity meter
US7168972B1 (en) 2006-04-26 2007-01-30 Itronix Corporation Computer interface jack
US7170425B2 (en) 2004-09-24 2007-01-30 Elster Electricity, Llc System and method for creating multiple operating territories within a meter reading system
US7187906B2 (en) 2004-04-26 2007-03-06 Elster Electricity, Llc Method and system for configurable qualification and registration in a fixed network automated meter reading system
US20070063868A1 (en) 2005-09-02 2007-03-22 Elster Electricity, Llc Multipurpose interface for an automated meter reading device
US7196673B2 (en) 2001-11-26 2007-03-27 Itron Electricity Metering, Inc. Embedded antenna apparatus for utility metering applications
US20070073866A1 (en) 2005-09-28 2007-03-29 Elster Electricity, Llc Ensuring automatic season change demand resets in a mesh type network of telemetry devices
US7209049B2 (en) 2004-02-19 2007-04-24 Itron, Inc. Distributed meter reading terminal
US20070091548A1 (en) 2005-10-14 2007-04-26 Landis+Gyr, Inc. Meter with reduced internal temperature rise and associated method
US20070096769A1 (en) 2005-11-03 2007-05-03 Elster Electricity, Llc Electronic meter supporting added functionality
US7218998B1 (en) 2005-07-11 2007-05-15 Neale Stephen D System and method for limiting power demand in an energy delivery system
US7224158B2 (en) 2002-05-29 2007-05-29 Landis+Gyr Ag Circuit arrangement and a method for compensating changes of a transfer factor of a magnetic field sensor arrangement
US20070124262A1 (en) 2005-11-28 2007-05-31 Elster Electricity, Llc Programming electronic meter settings using a bandwidth limited communications channel
US20070124109A1 (en) 2005-11-29 2007-05-31 Elster Electricity, Llc Fuzzy time-of-use metering and consumption monitoring using load profile data from relative time transmit-only devices
US7227350B2 (en) 2004-03-18 2007-06-05 Elster Electricity, Llc Bias technique for electric utility meter
US7230972B2 (en) 2003-05-07 2007-06-12 Itron, Inc. Method and system for collecting and transmitting data in a meter reading system
US7236498B1 (en) 1998-04-23 2007-06-26 Landis+Gry Ag Method for selecting an outstation using a control center in a transmission system
US20070147268A1 (en) 2005-12-23 2007-06-28 Elster Electricity, Llc Distributing overall control of mesh AMR LAN networks to WAN interconnected collectors
US7239250B2 (en) 2004-04-26 2007-07-03 Elster Electricity, Llc System and method for improved transmission of meter data
US20070177319A1 (en) 2003-11-07 2007-08-02 Responsiveload Limited Responsive electricity grid substation
US7262709B2 (en) 2004-04-26 2007-08-28 Elster Electricity, Llc System and method for efficient configuration in a fixed network automated meter reading system
US20070200729A1 (en) 2006-02-16 2007-08-30 Elster Electricity, Llc In-home display that communicates with a fixed network meter reading system
US20070205915A1 (en) 2006-02-16 2007-09-06 Elster Electricty, Llc Load control unit in communication with a fixed network meter reading system
US20070213880A1 (en) 2006-03-09 2007-09-13 Ehlers Gregory A System and method for demand limiting resistive load management
US20070222421A1 (en) 2005-10-21 2007-09-27 Schweitzer Engineering Laboratories, Inc. Apparatus and methods for controlling operation of a single-phase voltage regulator in a three-phase power system
US20070229305A1 (en) 2003-07-24 2007-10-04 Bonicatto Damian G Data Communication Over Power Lines
US7283062B2 (en) 2004-07-28 2007-10-16 Itron, Inc. Mapping in mobile data collection systems, such as for utility meter reading and related applications
US7283916B2 (en) 2004-07-02 2007-10-16 Itron, Inc. Distributed utility monitoring, such as for monitoring the quality or existence of a electrical, gas, or water utility
US20070257813A1 (en) 2006-02-03 2007-11-08 Silver Spring Networks Secure network bootstrap of devices in an automatic meter reading network
US20070262768A1 (en) 2006-05-05 2007-11-15 Elster Electricity Llc Fractional sampling of electrical energy
US7298134B2 (en) 2004-10-12 2007-11-20 Elster Electricity, Llc Electrical-energy meter adaptable for optical communication with various external devices
US7298135B2 (en) 1993-03-26 2007-11-20 Itron, Inc. Electronic revenue meter with automatic service sensing
US20070271006A1 (en) 2006-05-18 2007-11-22 Gridpoint, Inc. Modular energy control system
US7315162B2 (en) 2004-03-18 2008-01-01 Elster Electricity, Llc Reducing power consumption of electrical meters
WO2008003033A2 (en) 2006-06-29 2008-01-03 Edsa Micro Corporation Automatic real-time optimization and intelligent control of electrical power distribution and transmission systems
US20080001779A1 (en) 2004-03-30 2008-01-03 Itron Inc. Frequency Shift Compensation, Such as for Use In a Wireless Utility Meter Reading Environment
US7317404B2 (en) 2004-01-14 2008-01-08 Itron, Inc. Method and apparatus for collecting and displaying consumption data from a meter reading system
US20080010212A1 (en) 2006-06-22 2008-01-10 Itron, Inc. System and method for storing metering data while increasing memory endurance
US20080007247A1 (en) 2006-06-13 2008-01-10 Itron, Inc. Filtering techniques to remove noise from a periodic signal and Irms calculations
US20080007426A1 (en) 2006-06-13 2008-01-10 Itron, Inc Modified use of a standard message protocol for inter-module communications within a utility meter
US20080024115A1 (en) 2006-06-14 2008-01-31 Itron, Inc. Printed circuit board connector for utility meters
US7327998B2 (en) 2004-12-22 2008-02-05 Elster Electricity, Llc System and method of providing a geographic view of nodes in a wireless network
US7336200B2 (en) 2003-09-05 2008-02-26 Itron, Inc. Data communication protocol in an automatic meter reading system
EA009685B1 (en) 2003-06-05 2008-02-28 Энфо Бродкаст Ас A method and a system for automatic management of demand for non-durables
US20080062055A1 (en) 2006-09-11 2008-03-13 Elster Electricity, Llc Printed circuit notch antenna
US7346030B2 (en) 2003-09-26 2008-03-18 Itron, Inc. Processing gain for wireless communication, such as in automatic data collection systems for public utility data collection
US20080079741A1 (en) 2006-09-28 2008-04-03 Landisinc. External Access To Meter Display
US20080088475A1 (en) 2006-09-28 2008-04-17 Landis+Gyr, Inc. Utility Meter with Communication System Diplays
US7362236B2 (en) 2004-12-06 2008-04-22 Itron, Inc. Mobile utility data collection system with voice technology, such as for data collection relating to an electric, gas, or water utility
US20080097707A1 (en) 2006-10-06 2008-04-24 Landis+Gyr, Inc. VA metering in polyphase systems
US7365687B2 (en) 2005-04-22 2008-04-29 Elster Electricity, Llc Antenna with disk radiator used in automatic meter reading (AMR) device
US20080111526A1 (en) 2006-11-15 2008-05-15 Elster Electricity, Llc Input current or voltage limited power supply
US20080116906A1 (en) 2006-09-28 2008-05-22 Landis&plus; Gyr, Inc. Apparatus and method for metering contact integrity
US20080144548A1 (en) 2006-12-14 2008-06-19 Elster Electricity, Llc Optimization of redundancy and throughput in an automated meter data collection system using a wireless network
US20080143491A1 (en) 2006-12-13 2008-06-19 Deaver Brian J Power Line Communication Interface Device and Method
US7417557B2 (en) 2003-05-07 2008-08-26 Itron, Inc. Applications for a low cost receiver in an automatic meter reading system
US20080204953A1 (en) 2007-02-26 2008-08-28 Elster Electricity Llc. System and method for detecting the presence of an unsafe line condition in a disconnected power meter
US7421205B2 (en) 2003-07-15 2008-09-02 Landis+Gyr, Inc. Infrared receiver for residential electricity meter
US20080218164A1 (en) 2007-03-05 2008-09-11 Sensus Metering Systems Automated meter reader
US20080219210A1 (en) 2007-03-09 2008-09-11 Elster Electricity, Llc Reconfigurable mobile mode and fixed network mode endpoint meters
US20080266133A1 (en) 2006-09-28 2008-10-30 Landis+Gyr,Inc. Method and Arrangement for Communicating with a Meter Peripheral Using a Meter Optical Port
WO2008144860A1 (en) 2007-05-29 2008-12-04 Siemens Ltda Remote monitoring and control system of voltage regulators
US20090003356A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Node discovery and culling in wireless mesh communications networks
US20090003214A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Load management in wireless mesh communications networks
US20090003243A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Network utilities in wireless mesh communications networks
US20090003232A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Route and link evaluation in wireless mesh communications networks
US20090015234A1 (en) 2007-06-01 2009-01-15 Landis+Gyr, Inc. Full wave linear power supply voltage boost circuit
JP2009033811A (en) 2007-07-25 2009-02-12 Fuji Electric Systems Co Ltd Measuring and monitoring system, and apparatus and program for measuring its power quality
US20090062970A1 (en) 2007-08-28 2009-03-05 America Connect, Inc. System and method for active power load management
JP2009065817A (en) 2007-09-10 2009-03-26 Daihen Corp Voltage control method for distribution system
US7510422B2 (en) 2006-05-03 2009-03-31 Itron, Inc. Antenna breakaway device for utility pit meter system
US20090096211A1 (en) 2005-05-13 2009-04-16 Siemens Ag Wind Farm and Method for Controlling the Same
US7535378B2 (en) 2005-09-09 2009-05-19 Itron, Inc. RF meter reading system
US20090134996A1 (en) 2002-12-10 2009-05-28 White Ii Melvin Joseph Power Line Communication System and Method of Operating the Same
US20090146839A1 (en) 2006-05-17 2009-06-11 Tanla Solutions Limited Automated meter reading system and method thereof
US20090153356A1 (en) 2007-12-18 2009-06-18 Elster Electricity Llc. System and method for collecting information from utility meters
US20090167558A1 (en) 2007-12-26 2009-07-02 Elster Electricity, Llc Optimized data collection in a wireless fixed network metering system
US20090187284A1 (en) 2008-01-21 2009-07-23 Kreiss David G System and Method for Providing Power Distribution System Information
US7584066B2 (en) 2006-02-01 2009-09-01 Siemens Energy, Inc. Method for determining power flow in an electrical distribution system
US20090245270A1 (en) 2008-03-28 2009-10-01 Silver Spring Networks, Inc. Method and System of Updating Routing Information in a Communications Network
US20090256364A1 (en) 2008-04-09 2009-10-15 General Dynamics Itronix Corporation Over-center latch apparatus for a portable computing device
US20090265042A1 (en) 2008-04-17 2009-10-22 Mollenkopf James D System and Method for Providing Voltage Regulation in a Power Distribution System
US20090262642A1 (en) 2008-03-28 2009-10-22 Silver Spring Networks, Inc. Updating Routing and Outage Information in a Communications Network
US20090276170A1 (en) 2008-04-30 2009-11-05 Square D Company Automated voltage analysis in an electrical system using contextual data
US20090278708A1 (en) 2008-05-08 2009-11-12 Elster Electricity, Llc Power outage management and power support restoration for devices in a wireless network
US20090281673A1 (en) 2008-05-09 2009-11-12 Taft Jeffrey D Method and system for managing a power grid
US20090281679A1 (en) 2008-05-09 2009-11-12 Taft Jeffrey D Intelligent monitoring of an electrical utility grid
US20090287428A1 (en) 2008-05-13 2009-11-19 Elster Electricity, Llc Fractional samples to improve metering and instrumentation
US7626489B2 (en) 2002-12-10 2009-12-01 Current Technologies, Llc Power line communications device and method
US20090296431A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Single switch high efficiency power supply
US20090295371A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Actuator/wedge improvements to embedded meter switch
US20090299660A1 (en) 2008-05-29 2009-12-03 Dan Winter Method and System to Identify Utility Leaks
US20090299884A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Remote system upgrades in specific regulatory environments
US20090300191A1 (en) 2008-05-27 2009-12-03 Silver Spring Networks, Inc. Multi-Protocol Network Registration and Address Resolution
US7630863B2 (en) 2006-09-19 2009-12-08 Schweitzer Engineering Laboratories, Inc. Apparatus, method, and system for wide-area protection and control using power system data having a time component associated therewith
US20090310511A1 (en) 2008-06-13 2009-12-17 Silver Spring Networks, Inc. Methods and systems for dynamically configuring and managing communication network nodes at the mac sublayer
US20090309756A1 (en) 2008-06-13 2009-12-17 Elster Electricity, Llc Techniques For Limiting Demand From An electricity Meter With An Installed Relay
US20090309749A1 (en) 2008-06-13 2009-12-17 Silver Spring Networks Utility Network Interface Device With Visual Indication of Network Connectivity
US20090312881A1 (en) 2005-06-21 2009-12-17 Venturini Cheim Luiz Americo System and method for centralized monitoring of distributed power transformer
US20090319093A1 (en) 2008-03-31 2009-12-24 The Royal Institution For Advancement Of Learning/ Mcgill University Methods and processes relating to electricity power generation and distribution networks
US20100007522A1 (en) 2008-06-12 2010-01-14 Landis+Gyr, Inc. Programming of a Demand Triggered Service Disconnect Device from a Threshold in Amps
US20100013632A1 (en) 2008-07-18 2010-01-21 Salewske Tyson J Transceiver Interface for Power System Monitoring
US7656649B2 (en) 2007-12-26 2010-02-02 Elster Electricity, Llc Mechanical packaging apparatus and methods for an electrical energy meter
US20100026517A1 (en) 2008-01-04 2010-02-04 Itron, Inc. Utility data collection and reconfigurations in a utility metering system
US20100036624A1 (en) 2008-08-07 2010-02-11 Landis+Gyr, Inc. Stress condition logging in utility meter
US20100040042A1 (en) 2008-08-15 2010-02-18 Silver Spring Networks, Inc. Beaconing techniques in frequency hopping spread spectrum (fhss) wireless mesh networks
US20100045479A1 (en) 2008-08-20 2010-02-25 Landis+Gyr, Inc. Remote communications feedback for utility meter
US20100060259A1 (en) 2008-09-05 2010-03-11 Silver Spring Networks, Inc. Determining Electric Grid Endpoint Phase Connectivity
US20100061350A1 (en) 2008-09-09 2010-03-11 Silver Spring Networks, Inc. Multi-channel mesh nodes employing stacked responses
US20100074304A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Power Line Communication Using Frequency Hopping
US20100074176A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Meshed networking of access points in a utility network
US20100073193A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Transparent Routing in a Power Line Carrier Network
US20100094479A1 (en) 2008-10-10 2010-04-15 Keefe Robert A System and Method for Providing Voltage Control in a Power Line Distribution Network
US7702594B2 (en) 2004-09-24 2010-04-20 Elster Electricity, Llc System and method for automated configuration of meters
US20100103940A1 (en) 2008-10-23 2010-04-29 Silver Spring Networks, Inc. Rapid Dissemination of Bulk Information to Widely Dispersed Network Nodes
US20100117856A1 (en) 2008-11-11 2010-05-13 Itron, Inc. System and method of high volume import, validation and estimation of meter data
US20100128066A1 (en) 2007-05-01 2010-05-27 Noritake Co., Limited Image display method and apparatus
US20100134089A1 (en) 2008-12-03 2010-06-03 Sensus Usa Inc. System and method for phase load discovery
US20100150059A1 (en) 2008-12-15 2010-06-17 Silver Spring Networks, Inc. Static addressing of devices in a dynamically routed network
US7742430B2 (en) 2004-09-24 2010-06-22 Elster Electricity, Llc System for automated management of spontaneous node migration in a distributed fixed wireless network
US7746054B2 (en) 2007-02-26 2010-06-29 Elster Electricity, Llc System and method for detecting the presence of an unsafe line condition in a disconnected power meter
US7747534B2 (en) 2002-09-24 2010-06-29 Elster Electricity, Llc Utility power meter, metering system and method
US7756030B2 (en) 2006-09-15 2010-07-13 Itron, Inc. Downlink routing mechanism
US20100188257A1 (en) 2009-01-29 2010-07-29 Itron, Inc. In-home display
US20100188259A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Filtering of meter reading data
US20100188255A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Relative time system
US20100188263A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Prioritized collection of meter readings
US20100188938A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Measuring the accuracy of an endpoint clock from a remote device
US20100192001A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Device time adjustment for accurate data exchange
US20100188260A1 (en) 2009-04-20 2010-07-29 Itron, Inc. Endpoint classification and command processing
US20100188256A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Requested time adjustment for accurate data exchange
US20100188254A1 (en) 2009-01-29 2010-07-29 Itron Corporation Systems and methods for improving reception of data in wireless communication environments
US20100188258A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Time-divided communications in a metering system
US20100217550A1 (en) 2009-02-26 2010-08-26 Jason Crabtree System and method for electric grid utilization and optimization
WO2010129691A2 (en) 2009-05-07 2010-11-11 Powell Phillip W Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US7860672B2 (en) 2007-12-26 2010-12-28 Elster Electricity, Llc Method and apparatus for monitoring voltage in a meter network
US20110025130A1 (en) 2009-07-30 2011-02-03 Tigo Energy, Inc. Systems and method for limiting maximum voltage in solar photovoltaic power generation systems
CN102055201A (en) 2010-12-09 2011-05-11 北京四方继保自动化股份有限公司 Power system low-frequency oscillation mechanism analysis method based on micro-disturbance signal oscillation mode recognition
US20110208366A1 (en) 2010-02-19 2011-08-25 Accenture Global Services Gmbh Utility grid command filter system
US20120041696A1 (en) 2010-08-10 2012-02-16 Sensus Usa Inc. Electric Utility Meter To Stimulate Enhanced Functionality
US20120053751A1 (en) 2009-02-03 2012-03-01 Dong Energy Power A/S Distributed electrical power production system and method of control thereof
US20120136638A1 (en) 2010-11-25 2012-05-31 Schneider Electric Industries Sas Process and device to determine a structure of an electric power distribution network
US20120221265A1 (en) * 2011-02-28 2012-08-30 International Business Machines Corporation Systems and methods for phase identification
US20120249278A1 (en) 2011-03-31 2012-10-04 General Electric Company System and method for operating a tap changer
US8301314B2 (en) 2009-01-29 2012-10-30 S&C Electric Company System and method for providing voltage regulation in a power distribution network
US8583520B1 (en) 2012-10-24 2013-11-12 Causam Holdings, LLC System, method, and apparatus for settlement for participation in an electric power grid
US20140277813A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Maximizing of energy delivery system compatibility with voltage optimization using ami-based data control and analysis
US20140277814A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Electric power system control with measurement of energy demand and energy efficiency using t-distributions
US20140265574A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Management of energy demand and energy efficiency savings from voltage optimization on electric power systems using ami-based data analysis
US20140277788A1 (en) 2012-07-31 2014-09-18 Causam Energy, Inc. System, method, and data packets for messaging for electric power grid elements over a secure internet protocol network
US20140277796A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using ami-based data analysis
WO2014152408A2 (en) 2013-03-15 2014-09-25 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using ami-based data analysis
US20150088325A1 (en) 2012-07-31 2015-03-26 Causam Energy, Inc. System, method, and apparatus for electric power grid and network management of grid elements

Patent Citations (434)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3900842A (en) 1973-03-29 1975-08-19 Automated Technology Corp Remote automatic meter reading and control system
US3970898A (en) 1973-11-23 1976-07-20 Zellweger Uster Ag Method of automatically isolating a faulty section of a power line belonging to an electrical energy supply network, and arrangement for carrying out this method
US4054830A (en) 1974-03-25 1977-10-18 Landis Tool Company Regulated power supply
US4307380A (en) 1977-05-17 1981-12-22 Lgz Landis & Gyr Zug Ag Transmitting signals over alternating current power networks
US4361872A (en) 1977-12-29 1982-11-30 Lgz Landis & Gyr Zug Ag Measuring apparatus for determining the effective value of the power demand of an energy consumer over a period of calculation
US4310829A (en) 1978-04-27 1982-01-12 Lgz Landis & Gyr Zug Ag Transmitting device for communications equipment for generating a signal to be superimposed on an AC power supply network
US4309655A (en) 1978-06-23 1982-01-05 Lgz Landis & Gyr Zug Ag Measuring transformer
US4234904A (en) 1978-07-19 1980-11-18 Lgz Landis & Gyr Zug Ag Process and device for the protection of electrical energy supply systems controlled by means of audio-frequency
US4291377A (en) 1978-11-13 1981-09-22 Lgz Landis & Gyr Zug Ag. Apparatus for measuring electrical power
US4356553A (en) 1978-12-01 1982-10-26 Lgz Landis & Gyr Zug Ag Method for the measuring of electrical power
EP0020310A1 (en) 1979-05-28 1980-12-10 Arnaldo Spena A remote control direct electric load management system
US4302750A (en) 1979-08-03 1981-11-24 Compuguard Corporation Distribution automation system
US4434400A (en) 1980-05-02 1984-02-28 Lgz Landis & Gyr Zug Ag Circuit for supervising an electronic electricity meter
US4525668A (en) 1980-12-24 1985-06-25 Lgz Landis & Gyr Zug Ag System for measuring electrical output or energy
US4365302A (en) 1981-01-14 1982-12-21 Westinghouse Electric Corp. High accuracy AC electric energy metering system
US4450931A (en) 1981-03-09 1984-05-29 Ngk Insulators, Ltd. Structure for decreasing low frequency air vibration
JPS57148533A (en) 1981-03-10 1982-09-13 Tokyo Shibaura Electric Co Method of operating substation facility
US4686752A (en) 1982-06-25 1987-08-18 Beckman Instruments, Inc. Method of forming slots in a material-retaining plate for a packed column reactor in an analytical instrument
US4513273A (en) 1983-03-02 1985-04-23 Lgz Landis & Gyr Zug Ag Transducer for current measurement
US4630220A (en) 1984-03-06 1986-12-16 Southern California Edison Company Voltage controller
US4686630A (en) 1984-09-27 1987-08-11 Process Systems, Inc. Load management control system and method
US4843310A (en) 1985-06-15 1989-06-27 Lgz Landis & Gyr Zug Ag Electricity meter with arrangement for monitoring core saturation incidents
US4894610A (en) 1985-09-14 1990-01-16 LOZ Landis & Gyr Zug AG Current-transformer arrangement for an electrostatic meter
US4791520A (en) 1986-03-08 1988-12-13 Sachsenwerk Aktiengesellschaft Fault protection for a medium voltage transformer branch
US4695737A (en) 1986-03-19 1987-09-22 Southern California Edison Microcomputer controlled power regulator system and method
JPS63299722A (en) 1987-05-28 1988-12-07 Hitachi Ltd Voltage regulation relay
US4853620A (en) 1987-08-06 1989-08-01 Lgz Landis & Gyr Zug Ag Circuit arrangement comprising multiplier circuits to find the sum of electrical power outputs for application in multi-phase electricity meters
US4881027A (en) 1987-08-06 1989-11-14 Lgz Landis & Gyr Zug Ag Circuit arrangement comprising input circuits to find a power output sum for application in multi-phase electricity meters
US4887028A (en) 1987-09-21 1989-12-12 Landis & Gyr Metering, Inc. Watthour meter with isolation transformers having a feedback loop
US4896106A (en) 1987-09-21 1990-01-23 Landis & Gyr Metering, Inc. Watthour meter for wye connected systems
US5128855A (en) 1988-06-08 1992-07-07 Lgz Landis & Gyr Zug Ag Building automation system operating installation control and regulation arrangement
US5032785A (en) 1989-03-31 1991-07-16 Landis & Gyr Betriebs Ag Arrangement for measuring an electrical power or energy
US5270639A (en) 1989-09-22 1993-12-14 Landis & Gyr Metering, Inc. Time of use register for use with a utility meter
US5066906A (en) 1989-09-22 1991-11-19 Landis & Gyr Metering, Inc. Time of use register for use with a utility meter
US5124624A (en) 1989-12-14 1992-06-23 Landis & Gyr Betriebs Ag Arrangement for electrical measurement
US5028862A (en) 1989-12-26 1991-07-02 Honeywell Inc. Voltage follower circuit for use in power level control circuits
US6373399B1 (en) 1990-02-15 2002-04-16 Itron, Inc. Wide area communications network for remote data generating stations
US6653945B2 (en) 1990-02-15 2003-11-25 Itron, Inc. Radio communication network for collecting data from utility meters
US6172616B1 (en) 1990-02-15 2001-01-09 Itron, Inc. Wide area communications network for remote data generating stations
US20030001754A1 (en) 1990-02-15 2003-01-02 Itron, Inc. Wide area communications network for remote data generating stations
US5673252A (en) 1990-02-15 1997-09-30 Itron, Inc. Communications protocol for remote data generating stations
US5963146A (en) 1990-02-15 1999-10-05 Itron, Inc. Wide area communications network for remote data generating stations
US20020158774A1 (en) 1990-02-15 2002-10-31 Itron, Inc. Radio communication network for collecting data from utility meters
US5249150A (en) 1990-05-03 1993-09-28 Landis & Gyr Betriebs Ag Process and circuit to determine estimates of the instantaneous value of parameters of at least one sinusoidal signal with constant and known frequency which is an additive component of a measuring signal
US5055766A (en) 1990-06-04 1991-10-08 Duke Power Company Voltage regulator compensation in power distribution circuits
US5136233A (en) 1991-04-09 1992-08-04 Iowa-Illinois Gas And Electric Company Means and method for controlling elecrical transformer voltage regulating tapchangers
US5602750A (en) 1991-05-31 1997-02-11 Itronix Corporation Administrative computer and testing apparatus
US5511108A (en) 1991-05-31 1996-04-23 Itronix Corporation Apparatus and method for performing and controlling testing of electrical equipment
US5272462A (en) 1991-06-03 1993-12-21 Merlin Gerin Remote transmission device by on-line carrier currents designed for control and monitoring of an electrical power distribution system, notably medium voltage
US5262715A (en) 1991-07-22 1993-11-16 Landis & Gyr Betriebs Ag Arrangement for the measurement of reactive power or reactive energy
US5475867A (en) 1992-02-06 1995-12-12 Itron, Inc. Distributed supervisory control and data acquisition system
US5343143A (en) 1992-02-11 1994-08-30 Landis & Gyr Metering, Inc. Shielded current sensing device for a watthour meter
US6762598B1 (en) 1992-02-21 2004-07-13 Elster Electricity, Llc Method for providing optical test signals for electronic meter testing
US6954061B2 (en) 1992-02-21 2005-10-11 Elster Electricity, Llc Method and apparatus for electronic meter testing
US6940268B2 (en) 1992-02-21 2005-09-06 Elster Electricity, Llc Apparatus for metering at least one type of electrical power over a predetermined range of service voltages
US7180282B2 (en) 1992-02-21 2007-02-20 Elster Electricity, Llc Apparatus for metering at least one type of electrical power over a predetermined range of service voltages
US20070115022A1 (en) 1992-02-21 2007-05-24 Elster Electricity, Llc Power supply having voltage blocking clamp
US20050270015A1 (en) 1992-02-21 2005-12-08 Elster Electricity, Llc Method and apparatus for electronic meter testing
US7239125B2 (en) 1992-02-21 2007-07-03 Elster Electricity, Llc Method and apparatus for electronic meter testing
US7339805B2 (en) 1992-02-21 2008-03-04 Elster Electricity, Llc Power supply having voltage blocking clamp
US6703823B1 (en) 1992-02-21 2004-03-09 Elster Electricity, Llc Method and apparatus for electronic meter testing
US5231347A (en) 1992-02-28 1993-07-27 Landis & Gyr Metering, Inc. Power factor matching in an AC power meter
US5298857A (en) 1992-04-06 1994-03-29 Landis & Gyr Metering, Inc. Electrical energy meter with a precision integrator for current measurement
US5466973A (en) 1992-04-29 1995-11-14 N.V. Geb Zuid-Holland West Delivery point voltage regulation in electric energy distribution networks
US5432507A (en) 1992-10-27 1995-07-11 Societa' Italiana Per Il Gas P.A. Method and network for operating a distribution network
US5422561A (en) 1992-11-23 1995-06-06 Southern California Edison Company Automated voltage and VAR control in power transmission and distribution networks
US7688061B2 (en) 1993-03-26 2010-03-30 Itron, Inc. Apparatus for electronically measuring electrical energy
US7639000B2 (en) 1993-03-26 2009-12-29 Itron, Inc. Apparatus for electronically measuring or distributing electrical energy
US6906507B2 (en) 1993-03-26 2005-06-14 Itron Electricity Metering, Inc. Electronic revenue meter with automatic service sensing
US7688060B2 (en) 1993-03-26 2010-03-30 Itron, Inc. Electronic revenue meter with automatic service sensing
US20100109650A1 (en) 1993-03-26 2010-05-06 Itron, Inc. Apparatus for electronically measuring or distributing electrical energy
US7298135B2 (en) 1993-03-26 2007-11-20 Itron, Inc. Electronic revenue meter with automatic service sensing
US20080068005A1 (en) 1993-03-26 2008-03-20 Itron, Inc. Electronic revenue meter with automatic service sensing
US20080068004A1 (en) 1993-03-26 2008-03-20 Itron, Inc. Electronic revenue meter with automatic service sensing
US20080068006A1 (en) 1993-03-26 2008-03-20 Itron, Inc. Electronic revenue meter with automatic service sensing
US5552696A (en) 1994-02-18 1996-09-03 Siemens Energy & Automation, Inc. Multiple setpoint configuration in a voltage regulator controller
US5736848A (en) 1994-09-05 1998-04-07 Landis & Gyr Technology Innovation Ag Analog-to-digital measurement and calibration system for electrical energy
US5604414A (en) 1994-09-15 1997-02-18 Landis & Gyr Energy Management Method and apparatus for adjusting overload compensation for a watthour meter
RU2066084C1 (en) 1994-09-21 1996-08-27 Российский институт радионавигации и времени Device for control of electric load
US5627759A (en) 1995-05-31 1997-05-06 Process Systems, Inc. Electrical energy meters having real-time power quality measurement and reporting capability
US5646512A (en) 1995-08-30 1997-07-08 Beckwith; Robert W. Multifunction adaptive controls for tapswitches and capacitors
US5610394A (en) 1996-04-29 1997-03-11 Itron, Inc. Rotation monitor disturbance neutralization system
US6026355A (en) 1996-09-18 2000-02-15 Itron, Inc. Solid state watt-hour meter using GMR sensor
JPH10164756A (en) 1996-11-28 1998-06-19 Hitachi Ltd Method and apparatus for controlling power system
WO1998026489A1 (en) 1996-12-09 1998-06-18 Target - Hi-Tech Electronics Ltd. APPARATUS FOR AND METHOD OF EVENLY DISTRIBUTING AN ELECTRICAL LOAD ACROSS AN n-PHASE POWER DISTRIBUTION NETWORK
RU2200364C2 (en) 1996-12-09 2003-03-10 Тарджет-Хай-Тек Электроникс Лтд. Device for uniform distribution of electric load among phases in n-phase power distribution network
US5903548A (en) 1996-12-19 1999-05-11 Itronix Corporation Portable electronic communications device having switchable LAN/WAN wireless communications features
US20040218616A1 (en) 1997-02-12 2004-11-04 Elster Electricity, Llc Remote access to electronic meters using a TCP/IP protocol suite
US7126494B2 (en) 1997-02-12 2006-10-24 Elster Electricity, Llc Remote access to electronic meters using a TCP/IP protocol suite
US7046682B2 (en) 1997-02-12 2006-05-16 Elster Electricity, Llc. Network-enabled, extensible metering system
US6900737B1 (en) 1997-02-12 2005-05-31 Elster Electricity, Llc Remote access to electronic meters using the short message service
US6747981B2 (en) 1997-02-12 2004-06-08 Elster Electricity, Llc Remote access to electronic meters using a TCP/IP protocol suite
US7505453B2 (en) 1997-02-12 2009-03-17 Elster Electricity, Llc Network-enabled, extensible metering system
US6684245B1 (en) 1997-04-08 2004-01-27 Elster Electricity, Llc Automatic meter reading system employing common broadcast command channel
US6218995B1 (en) 1997-06-13 2001-04-17 Itron, Inc. Telemetry antenna system
US20040070517A1 (en) 1997-09-05 2004-04-15 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US20040061625A1 (en) 1997-09-05 2004-04-01 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US20080238716A1 (en) 1997-09-05 2008-10-02 Silver Spring Networks, Inc. Gateway-Controlled Communications With a Meter In a Utility Network
US7277027B2 (en) 1997-09-05 2007-10-02 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US7064679B2 (en) 1997-09-05 2006-06-20 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US6006212A (en) 1997-09-17 1999-12-21 Itron, Inc. Time-of-use and demand metering in conditions of power outage with a mobile node
US5918380A (en) 1997-09-17 1999-07-06 Itron, Inc. Time-of-use and demand metering in conditions of power outage
US6219655B1 (en) 1997-09-17 2001-04-17 Itron, Cin. Method of RF-based communication
US6628207B1 (en) 1997-12-24 2003-09-30 Elster Electricity, Llc Method and apparatus for detecting and reporting a power outage
US6333975B1 (en) 1998-03-03 2001-12-25 Itron, Inc. Method and system for reading intelligent utility meters
US7236498B1 (en) 1998-04-23 2007-06-26 Landis+Gry Ag Method for selecting an outstation using a control center in a transmission system
US6778099B1 (en) 1998-05-01 2004-08-17 Elster Electricity, Llc Wireless area network communications module for utility meters
US6650249B2 (en) 1998-05-01 2003-11-18 Elster Electricity, Llc Wireless area network communications module for utility meters
US6590376B1 (en) 1998-05-28 2003-07-08 Landis+Gyr Ag Method of deriving a frequency of a pulse signal from alternate sources and method of calibrating same
US6757628B1 (en) 1998-07-14 2004-06-29 Landis+Gyr Inc. Multi-level transformer and line loss compensator and method
US6555997B1 (en) 1998-09-15 2003-04-29 Landis+Gyr Ag Electricity meter and an input module for an electricity meter
US6636893B1 (en) 1998-09-24 2003-10-21 Itron, Inc. Web bridged energy management system and method
US6700902B1 (en) 1998-10-19 2004-03-02 Elster Electricity, Llc Method and system for improving wireless data packet delivery
US20090284251A1 (en) 1998-12-01 2009-11-19 Itron, Inc. Modular meter configuration and methodology
US6885185B1 (en) 1998-12-01 2005-04-26 Itron Electricity Metering, Inc. Modular meter configuration and methodology
US7701199B2 (en) 1998-12-01 2010-04-20 Itron, Inc. Modular meter configuration and methodology
US6940711B2 (en) 1999-01-27 2005-09-06 Elster Electricity, Llc Advanced instrument packaging for electronic energy meter
US6982390B2 (en) 1999-01-27 2006-01-03 Elster Electricity, Llc Advanced instrument packaging for electronic energy meter
US20040119458A1 (en) 1999-01-27 2004-06-24 Elster Electricity, Llc Advanced instrument packaging for electronic energy meter
US6417729B1 (en) 1999-02-18 2002-07-09 Itron, Inc. Linear power control loop
US6373236B1 (en) 1999-02-18 2002-04-16 Itron, Inc. Temperature compensated power detector
US20080238714A1 (en) 1999-02-23 2008-10-02 Silver Spring Networks, Inc. Utility Network Communications Using Meter Identifiers
US20080224891A1 (en) 1999-02-23 2008-09-18 Silver Spring Networks, Inc. Commodity Monitoring Network
US20040066310A1 (en) 1999-02-23 2004-04-08 Silver Spring Networks, Inc Electronic electric meter for networked meter reading
US20080204272A1 (en) 1999-02-23 2008-08-28 Silver Spring Networks, Inc. Utility Meter With Virtual Shut-Off Function
US20030122686A1 (en) 1999-02-23 2003-07-03 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US20080018492A1 (en) 1999-02-23 2008-01-24 Silver Spring Networks, Inc. Electronic electric meter for networked meter reading
US6747446B1 (en) 1999-09-24 2004-06-08 Landis+Gyr Inc. Arrangement for providing external access to functionality switches in a utility meter
US6988043B1 (en) 1999-10-21 2006-01-17 Landis+Gyr Inc. External transformer correction in an electricity meter
US6756914B1 (en) 1999-11-12 2004-06-29 Itron, Inc. Low impedance encoder for a utility meter
US6618684B1 (en) 2000-01-26 2003-09-09 Elster Electricity, Llc System and method for digitally compensating frequency and temperature induced errors in amplitude and phase shift in current sensing of electronic energy meters
US6947854B2 (en) 2000-02-29 2005-09-20 Quadlogic Controls Corporation System and method for on-line monitoring and billing of power consumption
US6873144B2 (en) 2000-04-07 2005-03-29 Landis+Gyr Inc. Electronic meter having random access memory with passive nonvolatility
US6633823B2 (en) 2000-07-13 2003-10-14 Nxegen, Inc. System and method for monitoring and controlling energy usage
US20020109607A1 (en) 2000-07-21 2002-08-15 Itron, Inc. Spread spectrum meter reading system utilizing low-speed/high-power frequency hopping
US7283580B2 (en) 2000-07-21 2007-10-16 Itron, Inc. Spread spectrum meter reading system utilizing low-speed/high-power frequency hopping
US20060056493A1 (en) 2000-08-01 2006-03-16 Itron, Inc. Frequency hopping spread spectrum system with high sensitivity tracking and synchronization for frequency unstable signals
US6868293B1 (en) 2000-09-28 2005-03-15 Itron, Inc. System and method for energy usage curtailment
US20020128748A1 (en) 2000-12-15 2002-09-12 Alexander Krakovich Configurable switchgear system
US6738693B2 (en) 2000-12-20 2004-05-18 Landis+Gyr Inc. Multiple virtual meters in one physical meter
US7616420B2 (en) 2000-12-26 2009-11-10 Landis+Gyr, Inc. Excessive surge protection method and apparatus
US7561399B2 (en) 2000-12-26 2009-07-14 Landis+Gyr, Inc. Excessive surge protection method and apparatus
US20060126255A1 (en) 2000-12-26 2006-06-15 Landisinc. Excessive surge protection method and apparatus
US6847201B2 (en) 2001-01-29 2005-01-25 Landis+Gyr Ag Compensation circuit for the phase shift in electric meters for direct connection
US7005844B2 (en) 2001-02-07 2006-02-28 Landis & Gyr Ag Measuring circuit arrangement for electricity meters for direct connection
JP2002247780A (en) 2001-02-20 2002-08-30 Mitsubishi Electric Corp Power quality control operation support system and power quality control operation support method
US7091878B2 (en) 2001-02-28 2006-08-15 Landis+Gyr, Inc. Electrical service disconnect having tamper detection
US7362232B2 (en) 2001-02-28 2008-04-22 Landis+Gyr, Inc. Electrical service disconnect having external interface
US7545135B2 (en) 2001-02-28 2009-06-09 Landis+Gyr, Inc. Electrical service disconnect in a modular meter
US20060202858A1 (en) 2001-02-28 2006-09-14 Landisinc. Electrical service disconnect in a modular meter
US20060232433A1 (en) 2001-02-28 2006-10-19 Landisinc. Electrical service disconnect having external interface
US6667692B2 (en) 2001-06-29 2003-12-23 Landis+Gyr Inc. Electrical utility meter having harmonic data templates for power quality alarm thresholds
US6832135B2 (en) 2001-07-10 2004-12-14 Yingco Electronic Inc. System for remotely controlling energy distribution at local sites
US6859742B2 (en) 2001-07-12 2005-02-22 Landis+Gyr Inc. Redundant precision time keeping for utility meters
US7126493B2 (en) 2001-09-14 2006-10-24 Landis+Gyr Inc. Utility meter with external signal-powered transceiver
US20060261973A1 (en) 2001-09-14 2006-11-23 Landisinc. Utility meter with external signal-powered transceiver
US20060145890A1 (en) 2001-09-14 2006-07-06 Landisinc. Utility meter with external signal-powered transceiver
US6815942B2 (en) 2001-09-25 2004-11-09 Landis+Gyr, Inc. Self-calibrating electricity meter
US6892144B2 (en) 2001-09-25 2005-05-10 Landis+Gyr, Inc. Arrangement for providing sensor calibration information in a modular utility meter
US20050212689A1 (en) 2001-09-25 2005-09-29 Landis+Gyr, Inc. Utility meter power arrangements and methods
US6995685B2 (en) 2001-09-25 2006-02-07 Landis+Gyr, Inc. Utility meter power arrangements and methods
US6906637B2 (en) 2001-10-29 2005-06-14 Landis + Gyr, Inc. Utility disconnect controller
US7196673B2 (en) 2001-11-26 2007-03-27 Itron Electricity Metering, Inc. Embedded antenna apparatus for utility metering applications
US7671814B2 (en) 2001-11-26 2010-03-02 Itron, Inc. Embedded antenna apparatus for utility metering applications
US20100110617A1 (en) 2001-11-26 2010-05-06 Itron, Inc. Embedded antenna apparatus for utility metering applications
US6888876B1 (en) 2001-12-21 2005-05-03 Elster Electricity, Llc Frequency hopping spread spectrum communications system
US7043381B2 (en) 2002-01-29 2006-05-09 Hitachi, Ltd. Substation system
US6832169B2 (en) 2002-01-29 2004-12-14 Hitachi, Ltd. Substation system
US20060195229A1 (en) * 2002-04-01 2006-08-31 Programmable Control Services, Inc. Electrical power distribution control systems and processes
US7069117B2 (en) 2002-04-01 2006-06-27 Programmable Control Services, Inc. Electrical power distribution control systems and processes
US20030187550A1 (en) 2002-04-01 2003-10-02 Wilson Thomas L. Electrical power distribution control systems and processes
US7729810B2 (en) 2002-04-01 2010-06-01 Programable Control Services, Inc. Electrical power distribution control systems and processes
US6867707B1 (en) 2002-04-24 2005-03-15 Elster Electricity, Llc Automated on-site meter registration confirmation using a portable, wireless computing device
US6798353B2 (en) 2002-04-24 2004-09-28 Itron Electricity Metering, Inc. Method of using flash memory for storing metering data
US7224158B2 (en) 2002-05-29 2007-05-29 Landis+Gyr Ag Circuit arrangement and a method for compensating changes of a transfer factor of a magnetic field sensor arrangement
US6816538B2 (en) 2002-06-26 2004-11-09 Elster Electricity, Llc Frequency hopping spread spectrum decoder
US7020178B2 (en) 2002-06-26 2006-03-28 Elster Electricity, Llc Microprocessor decoder frequency hopping spread spectrum communications receiver
US7301476B2 (en) 2002-06-27 2007-11-27 Elster Electricity, Llc Dynamic self-configuring metering network
US20050024235A1 (en) 2002-06-27 2005-02-03 Elster Electricity, Llc Dynamic self-configuring metering network
US7145474B2 (en) 2002-06-27 2006-12-05 Elster Electricity, Llc Dynamic self-configuring metering network
US20060043961A1 (en) 2002-06-27 2006-03-02 Elster Electricity, Llc Electrical-energy meter
US7119713B2 (en) 2002-06-27 2006-10-10 Elster Electricity, Llc Dynamic self-configuring metering network
US20040222783A1 (en) 2002-06-27 2004-11-11 Elster Electricity, Llc Electrical-energy meter
US7274187B2 (en) 2002-06-27 2007-09-25 Elster Electricity, Llc Electrical-energy meter
US6838867B2 (en) 2002-06-27 2005-01-04 Elster Electricity, Llc Electrical-energy meter
US6989667B2 (en) 2002-06-27 2006-01-24 Elster Electricity, Llc Electrical-energy meter
US7312721B2 (en) 2002-06-28 2007-12-25 Elster Electricity, Llc Data collector for an automated meter reading system
US20060071812A1 (en) 2002-06-28 2006-04-06 Elster Electricity Llc Data collector for an automated meter reading system
US7084783B1 (en) 2002-08-13 2006-08-01 Elster Electricity, Llc Electronic meter with enhanced thermally managed communications systems and methods
JP2004096906A (en) 2002-08-30 2004-03-25 E-Plat Co Ltd System and method for power management, cubicle arrangement, measuring apparatus, communication apparatus, distribution board, server for power management
US7135850B2 (en) 2002-09-12 2006-11-14 Landis+Gyr, Inc. Electricity meter with power supply load management
US20060145685A1 (en) 2002-09-12 2006-07-06 Landis+Gyr, Inc. Electricity meter with power supply load management
US7009379B2 (en) 2002-09-12 2006-03-07 Landis & Gyr, Inc. Electricity meter with power supply load management
US7348769B2 (en) 2002-09-12 2008-03-25 Landis+Gyr, Inc. Electricity meter with power supply load management
US20060158177A1 (en) 2002-09-12 2006-07-20 Landis+Gyr, Inc.. Electricity meter with power supply load management
US7747534B2 (en) 2002-09-24 2010-06-29 Elster Electricity, Llc Utility power meter, metering system and method
US6773652B2 (en) 2002-10-02 2004-08-10 Elster Electricity, Llc Process for the manufacture of a cover system for an electrical-energy meter
US20050237047A1 (en) 2002-12-05 2005-10-27 Landisinc. Enhanced fault protection in electricity meter
US6882137B1 (en) 2002-12-05 2005-04-19 Landis+Gyr, Inc. Enhanced fault protection in electricity meter
US7112949B2 (en) 2002-12-05 2006-09-26 Landis+Gyr Inc. Enhanced fault protection in electricity meter
US7626489B2 (en) 2002-12-10 2009-12-01 Current Technologies, Llc Power line communications device and method
US20090134996A1 (en) 2002-12-10 2009-05-28 White Ii Melvin Joseph Power Line Communication System and Method of Operating the Same
US7154938B2 (en) 2002-12-31 2006-12-26 Itron, Inc. RF communications system utilizing digital modulation to transmit and receive data
US20040150575A1 (en) 2003-02-03 2004-08-05 Silver Spring Networks, Inc. Flush-mounted antenna and transmission system
US6859186B2 (en) 2003-02-03 2005-02-22 Silver Spring Networks, Inc. Flush-mounted antenna and transmission system
US7161455B2 (en) 2003-02-03 2007-01-09 Landis + Gyr Inc. Method and arrangement for securing sensors in an electricity meter
US20040192415A1 (en) 2003-03-25 2004-09-30 Silver Spring Networks, Inc. Wireless communication system
US7417557B2 (en) 2003-05-07 2008-08-26 Itron, Inc. Applications for a low cost receiver in an automatic meter reading system
US7230972B2 (en) 2003-05-07 2007-06-12 Itron, Inc. Method and system for collecting and transmitting data in a meter reading system
EA009685B1 (en) 2003-06-05 2008-02-28 Энфо Бродкаст Ас A method and a system for automatic management of demand for non-durables
US7149605B2 (en) 2003-06-13 2006-12-12 Battelle Memorial Institute Electrical power distribution control methods, electrical energy demand monitoring methods, and power management devices
US7075288B2 (en) 2003-07-01 2006-07-11 Itron, Inc. System and method for acquiring voltages and measuring voltage into and electrical service using a non-active current transformer
US20050110480A1 (en) 2003-07-01 2005-05-26 Itron Electricity Metering, Inc. System and method for acquiring voltages and measuring voltage into an electrical service using a non-active current transformer
US7421205B2 (en) 2003-07-15 2008-09-02 Landis+Gyr, Inc. Infrared receiver for residential electricity meter
US20070229305A1 (en) 2003-07-24 2007-10-04 Bonicatto Damian G Data Communication Over Power Lines
US20080129537A1 (en) 2003-09-05 2008-06-05 Itron, Inc. Data communication protocol in an automatic meter reading system
US7561062B2 (en) 2003-09-05 2009-07-14 Itron, Inc. System and method for automatic meter reading with mobile configuration
US7116243B2 (en) 2003-09-05 2006-10-03 Itron, Inc. System and method for automatic meter reading with mobile configuration
US7479895B2 (en) 2003-09-05 2009-01-20 Itron, Inc. Data communication protocol in an automatic meter reading system
US20070013549A1 (en) 2003-09-05 2007-01-18 Itron, Inc. System and method for automatic meter reading with mobile configuration
US7336200B2 (en) 2003-09-05 2008-02-26 Itron, Inc. Data communication protocol in an automatic meter reading system
US7346030B2 (en) 2003-09-26 2008-03-18 Itron, Inc. Processing gain for wireless communication, such as in automatic data collection systems for public utility data collection
US7119698B2 (en) 2003-10-16 2006-10-10 Itron, Inc. Consumptive leak detection system
US20050119930A1 (en) 2003-10-21 2005-06-02 Itron, Inc. Combined scheduling and management of work orders, such as for utility meter reading and utility servicing events
US7089125B2 (en) 2003-10-27 2006-08-08 Itron, Inc. Distributed asset optimization (DAO) system and method
US20050090995A1 (en) 2003-10-27 2005-04-28 Itron Inc. Distributed asset optimization (DAO) system and method
US20050119841A1 (en) 2003-11-06 2005-06-02 Landisinc. Method of timing demand and time-of-use functionality with external clock source
US20070177319A1 (en) 2003-11-07 2007-08-02 Responsiveload Limited Responsive electricity grid substation
US20050125104A1 (en) * 2003-12-05 2005-06-09 Wilson Thomas L. Electrical power distribution control systems and processes
US20080180274A1 (en) 2004-01-14 2008-07-31 Itron, Inc. Method and apparatus for collecting and displaying consumption data a from a meter reading system
US7317404B2 (en) 2004-01-14 2008-01-08 Itron, Inc. Method and apparatus for collecting and displaying consumption data from a meter reading system
US7209049B2 (en) 2004-02-19 2007-04-24 Itron, Inc. Distributed meter reading terminal
US7109882B2 (en) 2004-02-19 2006-09-19 Itron, Inc. Utility endpoint communication scheme, such as for sequencing the order of meter reading communications for electric, gas, and water utility meters.
US7315162B2 (en) 2004-03-18 2008-01-01 Elster Electricity, Llc Reducing power consumption of electrical meters
US7227350B2 (en) 2004-03-18 2007-06-05 Elster Electricity, Llc Bias technique for electric utility meter
US20080012550A1 (en) 2004-03-18 2008-01-17 Elster Electricity, Llc Reducing power consumption of electrical meters
US7417420B2 (en) 2004-03-18 2008-08-26 Elster Electricity, Llc Switch to bypass optical diode for reducing power consumption of electrical meters
US20080001779A1 (en) 2004-03-30 2008-01-03 Itron Inc. Frequency Shift Compensation, Such as for Use In a Wireless Utility Meter Reading Environment
US20060168804A1 (en) 2004-03-31 2006-08-03 Elster Electricity, Llc Method for providing an electrical connection
US20050218873A1 (en) 2004-04-05 2005-10-06 Elster Electricity, Llc Switching regulator with reduced conducted emissions
US7167804B2 (en) 2004-04-22 2007-01-23 Landis+Gyr, Inc. Utility meter having programmable pulse output
US20060001415A1 (en) 2004-04-22 2006-01-05 Landisinc. Utility meter having programmable pulse output
US7262709B2 (en) 2004-04-26 2007-08-28 Elster Electricity, Llc System and method for efficient configuration in a fixed network automated meter reading system
US7239250B2 (en) 2004-04-26 2007-07-03 Elster Electricity, Llc System and method for improved transmission of meter data
US7187906B2 (en) 2004-04-26 2007-03-06 Elster Electricity, Llc Method and system for configurable qualification and registration in a fixed network automated meter reading system
US20070236362A1 (en) 2004-04-26 2007-10-11 Elster Electricity Llc System and Method for Improved Transmission of Meter Data
US20050240314A1 (en) 2004-04-27 2005-10-27 Martinez Edwin A Method and apparatus for controlling and monitoring electrical power consumption
US20050251401A1 (en) 2004-05-10 2005-11-10 Elster Electricity, Llc. Mesh AMR network interconnecting to mesh Wi-Fi network
US20050251403A1 (en) 2004-05-10 2005-11-10 Elster Electricity, Llc. Mesh AMR network interconnecting to TCP/IP wireless mesh network
US7142106B2 (en) 2004-06-15 2006-11-28 Elster Electricity, Llc System and method of visualizing network layout and performance characteristics in a wireless network
US20050278440A1 (en) 2004-06-15 2005-12-15 Elster Electricity, Llc. System and method of visualizing network layout and performance characteristics in a wireless network
US7283916B2 (en) 2004-07-02 2007-10-16 Itron, Inc. Distributed utility monitoring, such as for monitoring the quality or existence of a electrical, gas, or water utility
US20060012935A1 (en) 2004-07-13 2006-01-19 Elster Electricity, Llc Transient protector circuit for multi-phase energized power supplies
US20100010700A1 (en) 2004-07-28 2010-01-14 Itron, Inc. Mapping in mobile data collection systems, such as for utility meter reading and related applications
US7729852B2 (en) 2004-07-28 2010-06-01 Itron, Inc. Mapping in mobile data collection systems, such as for utility meter reading and related applications
US7283062B2 (en) 2004-07-28 2007-10-16 Itron, Inc. Mapping in mobile data collection systems, such as for utility meter reading and related applications
US20060038548A1 (en) 2004-08-17 2006-02-23 Elster Electricity, Llc. High voltage regulator for an electric meter power supply
US7355867B2 (en) 2004-08-17 2008-04-08 Elster Electricity, Llc Power supply for an electric meter having a high-voltage regulator that limits the voltage applied to certain components below the normal operating input voltage
US7245511B2 (en) 2004-08-25 2007-07-17 Itron, Inc. Resistor dropper power supply with surge protection
US20060044851A1 (en) 2004-08-25 2006-03-02 Itron Electricity Metering, Inc. Resistor dropper power supply with surge protection
US20060044157A1 (en) 2004-08-27 2006-03-02 Itron Electricity Metering, Inc. Firmware power cycle routine
US20060055610A1 (en) 2004-08-27 2006-03-16 Itron Electricity Metering, Inc. Embedded antenna and filter apparatus and methodology
US20080129420A1 (en) 2004-08-27 2008-06-05 Itron, Inc. Embedded antenna and filter apparatus and methodology
US20060071810A1 (en) 2004-09-24 2006-04-06 Elster Electricity, Llc. System for automatically enforcing a demand reset in a fixed network of electricity meters
US7742430B2 (en) 2004-09-24 2010-06-22 Elster Electricity, Llc System for automated management of spontaneous node migration in a distributed fixed wireless network
US7702594B2 (en) 2004-09-24 2010-04-20 Elster Electricity, Llc System and method for automated configuration of meters
US7176807B2 (en) 2004-09-24 2007-02-13 Elster Electricity, Llc System for automatically enforcing a demand reset in a fixed network of electricity meters
US7170425B2 (en) 2004-09-24 2007-01-30 Elster Electricity, Llc System and method for creating multiple operating territories within a meter reading system
US20060074556A1 (en) 2004-10-01 2006-04-06 Itron, Inc. Utility data collection system employing location data receiver, such as a dual USB port GPS receiver
US20060074601A1 (en) 2004-10-01 2006-04-06 Itron, Inc. Endpoint location file format, such as for use in mapping endpoints in a utility meter reading system
US7298134B2 (en) 2004-10-12 2007-11-20 Elster Electricity, Llc Electrical-energy meter adaptable for optical communication with various external devices
US7079962B2 (en) 2004-10-20 2006-07-18 Itron, Inc. Automated utility meter reading system with variable bandwidth receiver
US20060085147A1 (en) 2004-10-20 2006-04-20 Itron, Inc. Automated utility meter reading system with variable bandwidth receiver
US7516026B2 (en) 2004-10-20 2009-04-07 Itron, Inc. Automated utility meter reading system with variable bandwidth receiver
US7453373B2 (en) 2004-10-29 2008-11-18 Itron, Inc. Integrated meter module and utility metering system
US20060114121A1 (en) 2004-10-29 2006-06-01 Itron, Inc. Integrated meter module and utility metering system
US7362236B2 (en) 2004-12-06 2008-04-22 Itron, Inc. Mobile utility data collection system with voice technology, such as for data collection relating to an electric, gas, or water utility
US7327998B2 (en) 2004-12-22 2008-02-05 Elster Electricity, Llc System and method of providing a geographic view of nodes in a wireless network
US7761249B2 (en) 2005-01-14 2010-07-20 Landis+Gyr, Inc. Utility meter having RF protection
US20060158348A1 (en) 2005-01-14 2006-07-20 Landisinc. Utility meter having RF protection
JP2006208047A (en) 2005-01-25 2006-08-10 Muroran Institute Of Technology Multipoint simultaneous measurement data processor and processing method
US20060206433A1 (en) 2005-03-11 2006-09-14 Elster Electricity, Llc. Secure and authenticated delivery of data from an automated meter reading system
US7308370B2 (en) 2005-03-22 2007-12-11 Elster Electricity Llc Using a fixed network wireless data collection system to improve utility responsiveness to power outages
US20060217936A1 (en) 2005-03-22 2006-09-28 Elster Electricity Llc Using a fixed network wireless data collection system to improve utility responsiveness to power outages
US20060224335A1 (en) 2005-03-29 2006-10-05 Elster Electricity, Llc Collecting interval data from a relative time battery powered automated meter reading devices
US7365687B2 (en) 2005-04-22 2008-04-29 Elster Electricity, Llc Antenna with disk radiator used in automatic meter reading (AMR) device
US20090096211A1 (en) 2005-05-13 2009-04-16 Siemens Ag Wind Farm and Method for Controlling the Same
US20090312881A1 (en) 2005-06-21 2009-12-17 Venturini Cheim Luiz Americo System and method for centralized monitoring of distributed power transformer
US7218998B1 (en) 2005-07-11 2007-05-15 Neale Stephen D System and method for limiting power demand in an energy delivery system
US7495578B2 (en) 2005-09-02 2009-02-24 Elster Electricity, Llc Multipurpose interface for an automated meter reading device
US20070063868A1 (en) 2005-09-02 2007-03-22 Elster Electricity, Llc Multipurpose interface for an automated meter reading device
US20100007521A1 (en) 2005-09-09 2010-01-14 Itron, Inc. Rf meter reading system
US20090224940A1 (en) 2005-09-09 2009-09-10 Itron, Inc. Rf meter reading system
US7535378B2 (en) 2005-09-09 2009-05-19 Itron, Inc. RF meter reading system
US20070073866A1 (en) 2005-09-28 2007-03-29 Elster Electricity, Llc Ensuring automatic season change demand resets in a mesh type network of telemetry devices
US7308369B2 (en) 2005-09-28 2007-12-11 Elster Electricity Llc Ensuring automatic season change demand resets in a mesh type network of telemetry devices
US7471516B2 (en) 2005-10-14 2008-12-30 Landis+Gyr, Inc. Meter with reduced internal temperature rise and associated method
US20070091548A1 (en) 2005-10-14 2007-04-26 Landis+Gyr, Inc. Meter with reduced internal temperature rise and associated method
US20070222421A1 (en) 2005-10-21 2007-09-27 Schweitzer Engineering Laboratories, Inc. Apparatus and methods for controlling operation of a single-phase voltage regulator in a three-phase power system
US20070096769A1 (en) 2005-11-03 2007-05-03 Elster Electricity, Llc Electronic meter supporting added functionality
US7504821B2 (en) 2005-11-03 2009-03-17 Elster Electricity, Llc Auxiliary power supply for supplying power to additional functions within a meter
US20070124262A1 (en) 2005-11-28 2007-05-31 Elster Electricity, Llc Programming electronic meter settings using a bandwidth limited communications channel
US7583203B2 (en) 2005-11-28 2009-09-01 Elster Electricity, Llc Programming electronic meter settings using a bandwidth limited communications channel
US7236908B2 (en) 2005-11-29 2007-06-26 Elster Electricity, Llc Fuzzy time-of-use metering and consumption monitoring using load profile data from relative time transmit-only devices
US20070124109A1 (en) 2005-11-29 2007-05-31 Elster Electricity, Llc Fuzzy time-of-use metering and consumption monitoring using load profile data from relative time transmit-only devices
US20070147268A1 (en) 2005-12-23 2007-06-28 Elster Electricity, Llc Distributing overall control of mesh AMR LAN networks to WAN interconnected collectors
US7584066B2 (en) 2006-02-01 2009-09-01 Siemens Energy, Inc. Method for determining power flow in an electrical distribution system
US20070257813A1 (en) 2006-02-03 2007-11-08 Silver Spring Networks Secure network bootstrap of devices in an automatic meter reading network
US7427927B2 (en) 2006-02-16 2008-09-23 Elster Electricity, Llc In-home display communicates with a fixed network meter reading system
US7545285B2 (en) 2006-02-16 2009-06-09 Elster Electricity, Llc Load control unit in communication with a fixed network meter reading system
US20070205915A1 (en) 2006-02-16 2007-09-06 Elster Electricty, Llc Load control unit in communication with a fixed network meter reading system
US20070200729A1 (en) 2006-02-16 2007-08-30 Elster Electricity, Llc In-home display that communicates with a fixed network meter reading system
US20070213880A1 (en) 2006-03-09 2007-09-13 Ehlers Gregory A System and method for demand limiting resistive load management
US7168972B1 (en) 2006-04-26 2007-01-30 Itronix Corporation Computer interface jack
US7510422B2 (en) 2006-05-03 2009-03-31 Itron, Inc. Antenna breakaway device for utility pit meter system
US7756651B2 (en) 2006-05-05 2010-07-13 Elster Electricity, Llc Fractional sampling of electrical energy
US20070262768A1 (en) 2006-05-05 2007-11-15 Elster Electricity Llc Fractional sampling of electrical energy
US20090146839A1 (en) 2006-05-17 2009-06-11 Tanla Solutions Limited Automated meter reading system and method thereof
US20070271006A1 (en) 2006-05-18 2007-11-22 Gridpoint, Inc. Modular energy control system
US20080007247A1 (en) 2006-06-13 2008-01-10 Itron, Inc. Filtering techniques to remove noise from a periodic signal and Irms calculations
US20080007426A1 (en) 2006-06-13 2008-01-10 Itron, Inc Modified use of a standard message protocol for inter-module communications within a utility meter
US20080024115A1 (en) 2006-06-14 2008-01-31 Itron, Inc. Printed circuit board connector for utility meters
US7540766B2 (en) 2006-06-14 2009-06-02 Itron, Inc. Printed circuit board connector for utility meters
US20080010212A1 (en) 2006-06-22 2008-01-10 Itron, Inc. System and method for storing metering data while increasing memory endurance
WO2008003033A2 (en) 2006-06-29 2008-01-03 Edsa Micro Corporation Automatic real-time optimization and intelligent control of electrical power distribution and transmission systems
US7696941B2 (en) 2006-09-11 2010-04-13 Elster Electricity, Llc Printed circuit notch antenna
US20080062055A1 (en) 2006-09-11 2008-03-13 Elster Electricity, Llc Printed circuit notch antenna
US7756030B2 (en) 2006-09-15 2010-07-13 Itron, Inc. Downlink routing mechanism
US7764714B2 (en) 2006-09-15 2010-07-27 Itron, Inc. Crystal drift compensation in a mesh network
US7756078B2 (en) 2006-09-15 2010-07-13 Itron, Inc. Cell size management
US7630863B2 (en) 2006-09-19 2009-12-08 Schweitzer Engineering Laboratories, Inc. Apparatus, method, and system for wide-area protection and control using power system data having a time component associated therewith
US7683642B2 (en) 2006-09-28 2010-03-23 Landis+Gyr, Inc. Apparatus and method for metering contact integrity
US20080088475A1 (en) 2006-09-28 2008-04-17 Landis+Gyr, Inc. Utility Meter with Communication System Diplays
US20080116906A1 (en) 2006-09-28 2008-05-22 Landis&plus; Gyr, Inc. Apparatus and method for metering contact integrity
US20080079741A1 (en) 2006-09-28 2008-04-03 Landisinc. External Access To Meter Display
US20080266133A1 (en) 2006-09-28 2008-10-30 Landis+Gyr,Inc. Method and Arrangement for Communicating with a Meter Peripheral Using a Meter Optical Port
US7747400B2 (en) 2006-10-06 2010-06-29 Landis+Gyr, Inc. VA metering in polyphase systems
US20080097707A1 (en) 2006-10-06 2008-04-24 Landis+Gyr, Inc. VA metering in polyphase systems
US20080111526A1 (en) 2006-11-15 2008-05-15 Elster Electricity, Llc Input current or voltage limited power supply
US7486056B2 (en) 2006-11-15 2009-02-03 Elster Electricity, Llc Input current or voltage limited power supply
US20080143491A1 (en) 2006-12-13 2008-06-19 Deaver Brian J Power Line Communication Interface Device and Method
US20080144548A1 (en) 2006-12-14 2008-06-19 Elster Electricity, Llc Optimization of redundancy and throughput in an automated meter data collection system using a wireless network
US7746054B2 (en) 2007-02-26 2010-06-29 Elster Electricity, Llc System and method for detecting the presence of an unsafe line condition in a disconnected power meter
US20080204953A1 (en) 2007-02-26 2008-08-28 Elster Electricity Llc. System and method for detecting the presence of an unsafe line condition in a disconnected power meter
US20080218164A1 (en) 2007-03-05 2008-09-11 Sensus Metering Systems Automated meter reader
US20080219210A1 (en) 2007-03-09 2008-09-11 Elster Electricity, Llc Reconfigurable mobile mode and fixed network mode endpoint meters
US20100128066A1 (en) 2007-05-01 2010-05-27 Noritake Co., Limited Image display method and apparatus
WO2008144860A1 (en) 2007-05-29 2008-12-04 Siemens Ltda Remote monitoring and control system of voltage regulators
US20090015234A1 (en) 2007-06-01 2009-01-15 Landis+Gyr, Inc. Full wave linear power supply voltage boost circuit
US20100157838A1 (en) 2007-06-15 2010-06-24 Silver Spring Networks, Inc. Route and Link Evaluation in Wireless Mesh Communications Networks
US20090003232A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Route and link evaluation in wireless mesh communications networks
US20090003243A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Network utilities in wireless mesh communications networks
US20090003214A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Load management in wireless mesh communications networks
US20090003356A1 (en) 2007-06-15 2009-01-01 Silver Spring Networks, Inc. Node discovery and culling in wireless mesh communications networks
JP2009033811A (en) 2007-07-25 2009-02-12 Fuji Electric Systems Co Ltd Measuring and monitoring system, and apparatus and program for measuring its power quality
US20090062970A1 (en) 2007-08-28 2009-03-05 America Connect, Inc. System and method for active power load management
JP2009065817A (en) 2007-09-10 2009-03-26 Daihen Corp Voltage control method for distribution system
US20090153356A1 (en) 2007-12-18 2009-06-18 Elster Electricity Llc. System and method for collecting information from utility meters
US7860672B2 (en) 2007-12-26 2010-12-28 Elster Electricity, Llc Method and apparatus for monitoring voltage in a meter network
US7656649B2 (en) 2007-12-26 2010-02-02 Elster Electricity, Llc Mechanical packaging apparatus and methods for an electrical energy meter
US20090167558A1 (en) 2007-12-26 2009-07-02 Elster Electricity, Llc Optimized data collection in a wireless fixed network metering system
US20100026517A1 (en) 2008-01-04 2010-02-04 Itron, Inc. Utility data collection and reconfigurations in a utility metering system
US20090187284A1 (en) 2008-01-21 2009-07-23 Kreiss David G System and Method for Providing Power Distribution System Information
US20090262642A1 (en) 2008-03-28 2009-10-22 Silver Spring Networks, Inc. Updating Routing and Outage Information in a Communications Network
US20090245270A1 (en) 2008-03-28 2009-10-01 Silver Spring Networks, Inc. Method and System of Updating Routing Information in a Communications Network
US20090319093A1 (en) 2008-03-31 2009-12-24 The Royal Institution For Advancement Of Learning/ Mcgill University Methods and processes relating to electricity power generation and distribution networks
US20090256364A1 (en) 2008-04-09 2009-10-15 General Dynamics Itronix Corporation Over-center latch apparatus for a portable computing device
US20090265042A1 (en) 2008-04-17 2009-10-22 Mollenkopf James D System and Method for Providing Voltage Regulation in a Power Distribution System
US20090276170A1 (en) 2008-04-30 2009-11-05 Square D Company Automated voltage analysis in an electrical system using contextual data
US20090278708A1 (en) 2008-05-08 2009-11-12 Elster Electricity, Llc Power outage management and power support restoration for devices in a wireless network
US20090281673A1 (en) 2008-05-09 2009-11-12 Taft Jeffrey D Method and system for managing a power grid
US20090281679A1 (en) 2008-05-09 2009-11-12 Taft Jeffrey D Intelligent monitoring of an electrical utility grid
US20090287428A1 (en) 2008-05-13 2009-11-19 Elster Electricity, Llc Fractional samples to improve metering and instrumentation
US20090300191A1 (en) 2008-05-27 2009-12-03 Silver Spring Networks, Inc. Multi-Protocol Network Registration and Address Resolution
US20090299660A1 (en) 2008-05-29 2009-12-03 Dan Winter Method and System to Identify Utility Leaks
US20090296431A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Single switch high efficiency power supply
US20090294260A1 (en) 2008-05-30 2009-12-03 Itron,Inc. Meter with integrated high current switch
US20090299884A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Remote system upgrades in specific regulatory environments
US20090295371A1 (en) 2008-05-30 2009-12-03 Itron, Inc. Actuator/wedge improvements to embedded meter switch
US20100007522A1 (en) 2008-06-12 2010-01-14 Landis+Gyr, Inc. Programming of a Demand Triggered Service Disconnect Device from a Threshold in Amps
US20090309749A1 (en) 2008-06-13 2009-12-17 Silver Spring Networks Utility Network Interface Device With Visual Indication of Network Connectivity
US20090310511A1 (en) 2008-06-13 2009-12-17 Silver Spring Networks, Inc. Methods and systems for dynamically configuring and managing communication network nodes at the mac sublayer
US20090309756A1 (en) 2008-06-13 2009-12-17 Elster Electricity, Llc Techniques For Limiting Demand From An electricity Meter With An Installed Relay
US20100013632A1 (en) 2008-07-18 2010-01-21 Salewske Tyson J Transceiver Interface for Power System Monitoring
US20100036625A1 (en) 2008-08-07 2010-02-11 Landis+Gyr, Inc. Temperature Profiling in an Electricity Meter
US20100036624A1 (en) 2008-08-07 2010-02-11 Landis+Gyr, Inc. Stress condition logging in utility meter
US20100040042A1 (en) 2008-08-15 2010-02-18 Silver Spring Networks, Inc. Beaconing techniques in frequency hopping spread spectrum (fhss) wireless mesh networks
US20100045479A1 (en) 2008-08-20 2010-02-25 Landis+Gyr, Inc. Remote communications feedback for utility meter
US20100060259A1 (en) 2008-09-05 2010-03-11 Silver Spring Networks, Inc. Determining Electric Grid Endpoint Phase Connectivity
US20100061350A1 (en) 2008-09-09 2010-03-11 Silver Spring Networks, Inc. Multi-channel mesh nodes employing stacked responses
US20100074304A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Power Line Communication Using Frequency Hopping
US20100074176A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Meshed networking of access points in a utility network
US20100073193A1 (en) 2008-09-22 2010-03-25 Silver Spring Networks, Inc. Transparent Routing in a Power Line Carrier Network
US20100094479A1 (en) 2008-10-10 2010-04-15 Keefe Robert A System and Method for Providing Voltage Control in a Power Line Distribution Network
US20100103940A1 (en) 2008-10-23 2010-04-29 Silver Spring Networks, Inc. Rapid Dissemination of Bulk Information to Widely Dispersed Network Nodes
US20100117856A1 (en) 2008-11-11 2010-05-13 Itron, Inc. System and method of high volume import, validation and estimation of meter data
US20100134089A1 (en) 2008-12-03 2010-06-03 Sensus Usa Inc. System and method for phase load discovery
US20100150059A1 (en) 2008-12-15 2010-06-17 Silver Spring Networks, Inc. Static addressing of devices in a dynamically routed network
US20100188259A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Filtering of meter reading data
US20100188255A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Relative time system
US20100188257A1 (en) 2009-01-29 2010-07-29 Itron, Inc. In-home display
US20100188938A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Measuring the accuracy of an endpoint clock from a remote device
US20100192001A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Device time adjustment for accurate data exchange
US20100188258A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Time-divided communications in a metering system
US20100188256A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Requested time adjustment for accurate data exchange
US20100188254A1 (en) 2009-01-29 2010-07-29 Itron Corporation Systems and methods for improving reception of data in wireless communication environments
US8301314B2 (en) 2009-01-29 2012-10-30 S&C Electric Company System and method for providing voltage regulation in a power distribution network
US20100188263A1 (en) 2009-01-29 2010-07-29 Itron, Inc. Prioritized collection of meter readings
US20120053751A1 (en) 2009-02-03 2012-03-01 Dong Energy Power A/S Distributed electrical power production system and method of control thereof
US20100217550A1 (en) 2009-02-26 2010-08-26 Jason Crabtree System and method for electric grid utilization and optimization
US20100188260A1 (en) 2009-04-20 2010-07-29 Itron, Inc. Endpoint classification and command processing
WO2010129691A2 (en) 2009-05-07 2010-11-11 Powell Phillip W Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US8577510B2 (en) 2009-05-07 2013-11-05 Dominion Resources, Inc. Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US20100286840A1 (en) 2009-05-07 2010-11-11 Powell Phillip W Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US8437883B2 (en) 2009-05-07 2013-05-07 Dominion Resources, Inc Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US20130030591A1 (en) 2009-05-07 2013-01-31 Powell Phillip W Voltage conservation using advanced metering infrastructure and substation centralized voltage control
US20110025130A1 (en) 2009-07-30 2011-02-03 Tigo Energy, Inc. Systems and method for limiting maximum voltage in solar photovoltaic power generation systems
US20110208366A1 (en) 2010-02-19 2011-08-25 Accenture Global Services Gmbh Utility grid command filter system
US20120041696A1 (en) 2010-08-10 2012-02-16 Sensus Usa Inc. Electric Utility Meter To Stimulate Enhanced Functionality
US20120136638A1 (en) 2010-11-25 2012-05-31 Schneider Electric Industries Sas Process and device to determine a structure of an electric power distribution network
CN102055201A (en) 2010-12-09 2011-05-11 北京四方继保自动化股份有限公司 Power system low-frequency oscillation mechanism analysis method based on micro-disturbance signal oscillation mode recognition
US20120221265A1 (en) * 2011-02-28 2012-08-30 International Business Machines Corporation Systems and methods for phase identification
US20120249278A1 (en) 2011-03-31 2012-10-04 General Electric Company System and method for operating a tap changer
US20150088325A1 (en) 2012-07-31 2015-03-26 Causam Energy, Inc. System, method, and apparatus for electric power grid and network management of grid elements
US20140277788A1 (en) 2012-07-31 2014-09-18 Causam Energy, Inc. System, method, and data packets for messaging for electric power grid elements over a secure internet protocol network
US8583520B1 (en) 2012-10-24 2013-11-12 Causam Holdings, LLC System, method, and apparatus for settlement for participation in an electric power grid
US20140277814A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Electric power system control with measurement of energy demand and energy efficiency using t-distributions
US20140265574A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Management of energy demand and energy efficiency savings from voltage optimization on electric power systems using ami-based data analysis
US20140277813A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Maximizing of energy delivery system compatibility with voltage optimization using ami-based data control and analysis
US20140277796A1 (en) 2013-03-15 2014-09-18 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using ami-based data analysis
WO2014152408A2 (en) 2013-03-15 2014-09-25 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using ami-based data analysis
US20150094874A1 (en) 2013-03-15 2015-04-02 Dominion Resources, Inc. Electric power system control with measurement of energy demand and energy efficiency using t-distributions
US20150120078A1 (en) 2013-03-15 2015-04-30 Dominion Resources, Inc. Electric power system control with planning of energy demand and energy efficiency using ami-based data analysis
US20150137600A1 (en) 2013-03-15 2015-05-21 Dominion Resources, Inc. Management of energy demand and energy efficiency savings from voltage optimization on electric power systems using ami-based data analysis

Non-Patent Citations (20)

* Cited by examiner, † Cited by third party
Title
ANSI C84.1-2006; American National Standard for Electric Power Systems and Equipment Voltage Ratings (60 Hertz); National Electrical Manufactures Association, Approved Dec. 6, 2006, American National Standards Institute, Inc., pp. 1-23.
Bryon Flynn, "Key Smart Grid Applications", Protection & Control Journal, Jul. 2009, pp. 29-34.
Carl LaPlace, et al. Realizing the Smart Grid of the Future through AMI technology, 14 pages, Jun. 1, 2009.
Extended European Search Report dated Dec. 13, 2017 for European Application No. 14767612.6.
Extended European Search Report dated Jan. 26, 2017 for European Application No. 14769578.7.
Fletcher, R.H. et al., "Integrating Engineering and Economic Analysis of Conservation Voltage Reduction," Power Engineering Society Summer Meeting, 2002 IEEE vol. 2, pp. 725-730.
International Search Report and Written Opinion of the International searching Authority dated Aug. 7, 2014 on related PCT Appln. PCT/US2014/027310.
International Search Report and Written Opinion of the International searching Authority dated Dec. 20, 2010 on related PCT Appln. PCT/US2010/033751.
International Search Report and Written Opinion of the International searching Authority dated Jul. 24, 2014 on related PCT Appln. PCT/US2014/027332.
International Search Report and Written Opinion of the International searching Authority dated Jul. 29, 2014 on related PCT Appln. PCT/US2014/027299.
International Search Report and Written Opinion of the International searching Authority dated Sep. 5, 2014 on related PCT Appln. PCT/US2014/27361.
Kennedy, P.E. et al., "Conservation Voltage Reduction (CVR) at Snohmish County PUD," Transactions on Power Systems, vol. 6, No. 3, Aug. 1991, pp. 986-998.
M. A. Peskin et al. "Conservation Voltage Reduction with Feedback from Advanced Metering Infrastructure." 2012 IEEE PES Transmission and Distribution Conference and Exposition (T&D 2012) : Orlando, Florida, USA, May 7-10, 2012, IEEE, Piscataway, NJ, May 7, 2012, pp. 1-8.
N.Z. Dunnett et al. "Development of Closed Loop Voltage Control Simulator for Medium Voltage Distribution." Power Engineering Conference, 2009. AUPEC 2009. Australasian Universities, IEEE, Piscataway, NJ, USA, Sep. 27, 2009, pp. 1-5.
Paseraba, J., Secondary Voltage-Var Controls Applied to Static Compensators (STATCOMs) for Fast Voltage Control and Long Term Var Management, 2002 IEEE Power Engineering Society Summer Meeting. Jul. 25, 2002. Chicago, IL, vol. 2 pp. 753-761 <DOI: 10.1109/PESS.2002.1043415>.
R.C. Belvin et al. "Voltage Reduction Results on a 24-kV Circuit." 2012 IEEE PES Transmission and Distribution Conference and Exposition (T&D 2012) : Orlando, Florida, USA, May 7-10, 2012, IEEE Piscataway, NJ, May 7, 2012, pp. 1-4.
Williams, B.R., "Distribution Capacitor Automation Provides Integrated Control of Customer Voltage Levels and Distribution Reactive Power Flow," Southern California Edison Company, Power Industry Computer Application Conference, 1995, Conference Proceedings, pp. 215-220.
Willis, H. L., "Power Distribution Planning Reference Book." Second Edition, Revised and Expanded, Chapter 10, pp. 356-363 and 387, 2004.
Wilson, T. L., "Measurement and Verification of Distribution Voltage Optimization Results for the IEEE Power & Energy Society", 2010, pp. 1-9.
Wilson, Thomas L. "Measurement and Verification of Distribution Voltage Optimization Results for the IEEE Power & Energy Society", 2010, pp. 1-9.

Also Published As

Publication number Publication date
US20160164290A1 (en) 2016-06-09

Similar Documents

Publication Publication Date Title
EP3245707B1 (en) Building control system with optimization of equipment life cycle economic value while participating in ibdr and pbdr programs
EP3248266B1 (en) Building management system with electrical energy storage optimization based on statistical estimates of ibdr event probabilities
US10198458B2 (en) Intelligent electrical distribution grid control system data
Taieb et al. Forecasting uncertainty in electricity smart meter data by boosting additive quantile regression
Günter et al. Energy storage for grid services and applications: Classification, market review, metrics, and methodology for evaluation of deployment cases
EP2863285B1 (en) Methods and systems for controlling an electric network
Dvorkin et al. Assessing flexibility requirements in power systems
US10283968B2 (en) Power control system with power setpoint adjustment based on POI power limits
US9507367B2 (en) Method and system for dynamic stochastic optimal electric power flow control
US10418833B2 (en) Electrical energy storage system with cascaded frequency response optimization
US10742055B2 (en) Renewable energy system with simultaneous ramp rate control and frequency regulation
US20170103483A1 (en) Building management system with electrical energy storage optimization based on benefits and costs of participating in PBDR and IBDR programs
US10418832B2 (en) Electrical energy storage system with constant state-of charge frequency response optimization
US10389136B2 (en) Photovoltaic energy system with value function optimization
Paparoditis et al. Short-term load forecasting: the similar shape functional time-series predictor
US10222427B2 (en) Electrical energy storage system with battery power setpoint optimization based on battery degradation costs and expected frequency response revenue
US10855081B2 (en) Energy storage controller with battery life model
Giannakis et al. Monitoring and optimization for power grids: A signal processing perspective
US8706309B2 (en) Systems and method for obtaining a load model and related parameters based on load dynamics
Begovic et al. Impact of renewable distributed generation on power systems
Samad et al. Controls for smart grids: Architectures and applications
Pratt et al. The smart grid: an estimation of the energy and CO2 benefits
CN103197138B (en) A kind of intelligent electric meter and monitoring method with power supply reliability and rate of qualified voltage monitoring function
Rowe et al. A peak reduction scheduling algorithm for storage devices on the low voltage network
US20170102433A1 (en) Electrical energy storage system with battery power setpoint optimization using predicted values of a frequency regulation signal

Legal Events

Date Code Title Description
AS Assignment

Owner name: DOMINION RESOURCES, INC., VIRGINIA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HALL, EDMUND J.;TYLER, STEPHEN J.;REEL/FRAME:039389/0961

Effective date: 20160316

AS Assignment

Owner name: DOMINION ENERGY, INC., VIRGINIA

Free format text: CHANGE OF NAME;ASSIGNOR:DOMINION RESOURCES, INC.;REEL/FRAME:042466/0918

Effective date: 20170510

STCF Information on status: patent grant

Free format text: PATENTED CASE